TABLE OF CONTENTS 

DRAFT 

Environmental Impact Statement 

Continental Divide-Creston 

Natural Gas Development Project 

Volume II 

November 2012 
The BLM’s multiple-use mission is to sustain the health and productivity of the 

public lands for the use and enjoyment of present and future generations. The 

Bureau accomplishes this by managing such activities as outdoor recreation, 

livestock grazing, mineral development, and energy production, and by 

conserving natural, historical, cultural, and other resources on public lands. 

BLM/WY/PL-13/002+1310
 
 

 

TABLE OF CONTENTS 

VOLUME II. 

Appendix A: Summary of Scoping Comments by Category 

Appendix B: Plan of Development 

Appendix C: Best Management Practices and Conditions of Approval 

Appendix D: Paleontological Resources Program Guidance 

Appendix E: Reclamation Guidance 

Appendix F: Water Resources Supplemental Data 

Appendix G: Energy by Design – Cooperative Mitigation Planning for the CD-C Gas 

Field 

Appendix H: Occurrence Potential of Wildlife in the CD-C project area 

Appendix I: Wildlife Inventory, Monitoring, and Protection Plan 

Appendix J: Cultural Resources Management 

Appendix K: Hazardous Materials Management Summary 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 14, 2012 i 
APPENDIX A: SUMMARY OF SCOPING COMMENTS BY CATEGORY 

 

Table of Contents 

Introduction ........................................................................................................................... A-1 

 PHYSICAL RESOURCES................................................................................................. A-1
 

Soils .............................................................................................................................................. A-1
 

Water Resources ........................................................................................................................... A-2
 

Climate and Air Quality ................................................................................................................ A-4
 

 BIOLOGICAL RESOURCES ............................................................................................ A-5
 

Vegetation and Riparian/Wetland Communities ............................................................................A-5
 

Invasive, Non-native species ......................................................................................................... A-6
 

Terrestrial and Aquatic Wildlife .................................................................................................... A-6
 

Special Status Species ................................................................................................................... A-8
 

Wild Horses & Burros................................................................................................................... A-9
 

 HUMAN ENVIRONMENT................................................................................................ A-10
 

Visual Resources......................................................................................................................... A-10
 

Recreation ................................................................................................................................... A-10
 

Cultural and Historical Resources................................................................................................ A-11
 

Socioeconomics .......................................................................................................................... A-11
 

Transportation ............................................................................................................................. A-13
 

Noise .......................................................................................................................................... A-14
 

 MANAGEMENT ENVIRONMENT ................................................................................... A-15
 

Lands and Realty......................................................................................................................... A-15
 

Rangeland Management .............................................................................................................. A-15
 

Areas of Critical Environmental Concern .................................................................................... A-16
 

Wilderness .................................................................................................................................. A-16
 

General and Administrative Issues............................................................................................... A-16
 

Scoping and Approach ................................................................................................................ A-17
 

Alternatives Development ........................................................................................................... A-19
 

Directional Drilling ..................................................................................................................... A-20
 

Mitigation and Monitoring .......................................................................................................... A-20
 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

Introduction 

As described in Section 1.6, Public Participation, the BLM conducted public scoping for both the 

Creston/Blue Gap II and the Continental Divide-Creston Natural Gas Development projects. In the fall of 

2005, BLM published a Notice of Intent in the Federal Register and invited the public to comment on a 

proposal for more extensive development in the Creston/Blue Gap II natural gas field. A public meeting 

was held in Rawlins on October 13, 2005. During the scoping period on the Creston/Blue Gap II Project, 

the BLM received 29 individual comment letters, faxes, and e-mails. 

Very soon after the Creston/Blue Gap scoping process had been completed, BLM RFO received a 

proposal from BP America Production Company (BP), representing themselves and other leaseholders, to 

further develop lease holdings in the Continental Divide/Wamsutter II natural gas area. The BLM decided 

to combine this project with the Creston/Blue Gap project into a single EIS and initiated another scoping 

process for the newly named Continental Divide-Creston EIS. The BLM published a Notice of Intent for 

this larger Continental Divide-Creston project on March 3, 2006. A public meeting to discuss the project 

was held in Rawlins on April 6. In addition to the 29 comments received during the original scoping 

period, 21 comment letters, faxes, and e-mails were received for the combined Continental DivideCreston Project. Most of the respondents were the same for both projects. 

Section 1.6.2, Key Issues and Concerns, describes those issues raised during the course of scoping for 

both phases of the project that are considered central to the analysis of impacts in this EIS- those issues 

that have not already been addressed as matters of law or policy, that deal with resources of high value in 

the project area, and that would be directly affected by the BLM’s decision on natural-gas development in 

the project area. This Appendix includes a more comprehensive listing of the issues that were raised 

during the process. The Continental Divide-Creston Public Scoping Notice included a list of scoping 

questions representing preliminary issues identified by the BLM with regard to resources and 

management issues. These issues, shown below as BLM Scoping Questions, include air quality, cultural 

resources, land use, soils and vegetation, hydrology and water rights, wildlife, visual resources, noise, 

recreation, transportation, socioeconomic resources, and reclamation. 

BLM’s scoping questions and a summary of the public comments received are described below, 

categorized by resource and management issue. In some instances, BLM did not identify scoping 

questions for a particular issue; thus only comments are listed. 

 PHYSICAL RESOURCES 

Soils 

BLM Scoping Questions: 

	 Are there short-term, direct impacts to the soils in the project area? 

	 Are there long-range, indirect impacts to the soils resources in the project area? 

	 How much surface area will be disturbed and for how long? 

	 What provisions for interim reclamation will be made? 

	 What measures will be taken to minimize erosion and sedimentation once soil and vegetation is
 

removed from disturbed sites?
 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

Scoping Comments: 

 Consider effects of erosion from wind, and to a lesser degree, water 

 Consider mitigation measures that can reduce removal of topsoil and vegetation, and other practices 

that may have significant short-term impacts to soils. 

 BLM must protect against soil erosion by identifying and protecting fragile, steep, or highly erosive 

soils, including biological soil crusts. 

Water Resources 

BLM Scoping Questions: 

 What are the watershed characteristics of the project area? 

 What existing conditions of stream banks and streambeds might be affected by the proposal?
 

 What is the direction and magnitude of groundwater flows in the project area?
 

 What are the recharge and discharge characteristics of groundwater in the area, including the
 

relationship between ground and surface waters? 

 What are the existing qualities of surface and ground water in the project area? How will the project 

affect surface and ground water qualities?
 

 How will produced water from coalbed de-watering operations be utilized and/or disposed of?
 

 What measures will be taken to minimize erosion and sedimentation once soil and vegetation is
 

removed from disturbed sites? 

Scoping Comments: 

 Consider effects to water quality in the Colorado River.
 

 Consider degraded groundwater and surface water.
 

 Draining all the water from the ground lowers the ground level, provides no water for plants.
 

 Disclose whether any stream segments exceed water quality standards and/or are listed in the state’s
 

Clean Water Act. Determine if any planning and evaluation has been conducted on streams that 

have been evaluated as impaired, or if there is doubt as to whether any streams are achieving State 

water-quality standards. 

 BLM must insure that waters in the project area comply with state water quality standards and with 

sections 401 and 404 of the CWA. 

 Maintain a buffer zone and NSO around natural springs to protect water quality. Carefully evaluate 

the appropriate width of buffers and discourage all development or alteration of natural springs. 

 BLM must comply with its obligations under the ESA concerning salt and sediment loads to and 

depletions from Colorado River watersheds. 

	 Selenium content of produced water must be 2 μ/L to protect fish, waterfowl, shorebirds, and other 

wildlife. Due to “bioaccumulation” in living tissue, the amount of selenium discharged (not the 

concentration released) must be monitored and regulated. 

o Do not discharge produced water with selenium concentrations > 2μ/L into closed containment 

pits or ponds for disposal by evaporation. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

o	 Estimate selenium and other trace element concentrations in evaporation ponds using an 

appropriate model, over a period of years to determine if selenium and other trace elements 

could post a risk to migratory birds using the pond. 

	 To prevent migratory bird mortality for species using evaporative ponds: 

o	 Using an appropriate model, estimate the sodium concentrations in produced water within the 

evaporation pond over a period of years to determine if sodium could pose a risk to migratory 

birds landing on the pond. If the model shows that sodium concentrations would exceed 17,000 

mg/l, then the pond should be designed with effective wildlife exclusionary devices to prevent 

access by migratory birds, or other options should be considered for containment and disposal 

of produced water. 

o	 If the predictive model does not show an increasing trend in sodium concentrations, the pond 

should be monitored annually to verify whether levels are increasing over time. If 

concentrations exceed 17,0000 mg/L, netting or other effective wildlife exclusionary devices 

should be deployed to prevent access, or other options considered for containment and disposal 

of produced water. 

	 No surface disposal of produced water should be allowed due to increased salt loading within the 

Colorado River basin. In addition, it would alter the chemistry, suspended solids, water temperature 

and/or natural hydrograph of the watershed in the Muddy Creek drainage, which could result in 

elimination of native fish populations even if the water meets TDS loading set by the Colorado 

River Basin Salinity Control Forum in 2002. 

	 Evaluate the use of produced water to irrigate croplands in terms of potential land use changes. 

	 Analyze management of produced water through re-injection into underground reservoirs through 

National Pollution Discharge Elimination permits. 

	 Inject produced water from coalbed methane underground; no surface disposal. 

	 How are the formations identified for re-injection related to the formations that produce the springs 

that create the stream in the Muddy Creek drainage? 

	 Hydrostatic test water released during pipeline construction could alter stream channels, increase 

sediment loads, and introduce potentially toxic chemicals or invasive species. Avoid discharging 

hydrostatic test waters directly to streams; release them first into a temporary sediment retention 

basin if suspended solids concentration is significantly higher than receiving water. Use potable or 

freshwater well sources for hydrostatic test water. 

	 At no time should water from a surface source in one basin be discharged into another basin, which 

could spread nuisance species. 

	 Regarding pipeline construction and operations: 

o	 Pipeline crossings of perennial streams should be bored underneath the stream rather than 

trenching through it, especially Muddy Creek and its primary tributaries. 

o	 Install pipeline crossings through ephemeral streams by trenching, using riprap to stabilize 

stream banks. Place riprap from the channel bottom to the top of the high water line on the 

bank. Use double-ditching techniques to separate the top one-foot of stream-bottom substrate 

from deeper soil layers, and reconstruct by replacing deeper substrate first. 

o	 Locate pipelines that parallel drainages outside the100-year floodplain. Construct pipeline 

crossings at right angles to all riparian corridors and stream to minimize the area of disturbance. 

o	 Use the minimum practical width for rights-of-way where pipelines cross riparian areas and 

streams. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

o	 Any new road crossing of Muddy Creek proper is opposed; a bridge should be used to span the 

channel and riparian zone, and the structure should not impact or restrict flow in the channel on 

the 50-year flood plain. 

o	 For perennial tributaries in the Muddy Creek drainage, design road crossings to allow fish 

passage at all flows. Preferred structures in descending order: bridge spans with abutments on 

banks, bridge spans with center support, open-bottom box culverts, and round culverts with the 

bottom placed no less than one foot below existing stream grade. Perched culverts block fish 

passage and are unacceptable in any stream that supports a fishery. 

o	 Drilling should not be permitted on slopes exceeding 25%. 

o	 Design drill pad sites to drain storm water and other fluids into a reserve pit with capacity to 

intercept and hold excess precipitation. Line all reserve pits, irrespective of soil types, with an 

impermeable barrier to eliminate leaching. 

o	 Staging, refueling, and storage areas should be located away from riparian zones and flood 

plains. Keep all chemicals, solvents, and fuels at least 500 feet from streams and riparian areas. 

o	 Locate and construct all structures crossing intermittent and perennial streams so they do not 

decrease channel stability or increase water velocity. 

	 BLM must protect against degradation of water quality by implementing measures such as lining of 

reserve pits or pitless drilling. 

Climate and Air Quality 

BLM Scoping Questions: 

 What emission sources and values will be generated by the project?
 

 How will air quality impacts be evaluated and resources protected during development and 

operations?
 

Scoping Comments: 

	 General concern: long-range protection of visibility. 

	 The EIS should be consistent with the Rawlins Draft RMP/EIS, which proposed to use a
 

comparative, emissions-based approach.
 

	 BLM must assure full compliance with the Clean Air Act. 

	 Fully explain and interpret projected impacts, summarizing modeled results and the various methods 

and assumptions used so that the public can easily understand them for their significance. Include 

specific mitigation measures, such as improved diesel engine technology and fugitive dust control. 

	 Estimate potential future changes in emissions. Modeling should address cumulative emissions in 

the Rawlins Field Office planning area that affect the same areas as C/BGII. Include information in 

the DEIS regarding cumulative impacts from coal production in the vicinity. 

	 Address reasonably foreseeable gas and other development in the area, and possible changes in this 

and other proposed projects. For example, the Jonah Infill gas project suggests that improved diesel 

engine technology may be necessary for all future gas development projects in Southwestern 

Wyoming to protect Class I and other air resources. 

	 Disclose the effects of increases in Nox and other pollutant concentrations, including regional haze, 

and clarify control measures. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 The fugitive dust analysis should emphasize the Pm10 standard and percentages of emissions that are 

fine and coarse particles. Address near-field impacts of fugitive dust, and whether there is potential 

to approach NAAQS standards. 

	 Describe potential air impacts of venting and flaring, and whether BLM or the State of Wyoming 

are considering flare less flow back or similar technology as mitigation.
 

	 Address proposed and needed air monitoring. If BLM intends to add air monitoring stations,
 

describe the program in sufficient detail to ascertain locations and objectives of the monitoring
 

effort.
 

	 The EIS must analyze the cumulative effect on air quality, including all sensitive receptors 

potentially affected, and acknowledging all reasonably foreseeable emission sources. Additionally, 

BLM must ensure compliance with all air pollution standards and discuss all mitigation measures 

available to prevent air quality violations, increment exceedances and adverse impacts to AQRV, 

including visibility impairment in Class I areas. 

	 We request that BLM reject use of the Scheffe model for estimation of ozone pollution and use
 

instead an up-to-date photochemical model such as CAMx or CAMQ.
 

 BIOLOGICAL RESOURCES 

Vegetation and Riparian/Wetland Communities 

BLM Scoping Questions: 

 Are there short-term, direct impacts to the vegetation resources in the project area?
 

 Are there long-range, indirect impacts to the vegetation resources in the project area?
 

 How much surface area will be disturbed; for how long?
 

 What provisions for interim reclamation will be made?
 

 How will noxious weed populations be monitored/ controlled?
 

 What are the revegetation standards and requirements?
 

 Are there adequate reclamation bonds or other guarantees for reclamation of site disturbance?
 

 Will there be impacts to jurisdictional wetlands or Waters of the U.S.?
 

 How much surface area will be disturbed and for how long? 

 What provisions for interim reclamation will be made?
 

 What measures will be taken to minimize erosion and sedimentation once soil and vegetation is
 

removed from disturbed sites? 

Scoping Comments: 

	 BLM should conduct surveys to determine the location and characteristics of native plant 

communities and rare or special status species and insure compliance with EO 13112 relative to
 

invasive species.
 

	 Outline minimum reclamation standards that emphasize use of native plant species, postreclamation monitoring, and management.
 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 Riparian and wetland habitat buffer zones should preclude new surface-disturbing activities within 

the 100-year floodplain or within a designated buffer. Recommend buffer zones that include NSO 

stipulations and clarify if surface occupancy exemption may be granted, including the nature of its 

mitigation. Clarify if exemptions may be restricted based on the cumulative effects of similar 

actions in any one riparian area. 

 Take measures to avoid wetland losses in accordance with Section 404 of the Clean Water Act. 

 Inventory and fully describe wetlands that may be destroyed or degraded in terms of functions and 

values, and outline specific actions to minimize impacts and compensate for unavoidable impacts. 

 Avoid impacts to riparian areas; minimize and assess functions and values in areas of unavoidable 

impacts, and develop and implement measures to compensate unavoidable losses. 

Invasive, Non-native species 

BLM Scoping Questions: 

 How much surface area will be disturbed and for how long? 

 What provisions for interim reclamation will be made?
 

 How will noxious weed populations be monitored, and controlled?
 

Scoping Comments: 

	 Describe the current trend for weed infestations. Include the location of weed infestations within 

and surrounding the project area, the trend in infestations, specific measures for oil and gas leases, 

and the annual budget available to affected counties and BLM for invasive species control. 

	 BLM must provide measures to impede the invasion of noxious weeds. 

Terrestrial and Aquatic Wildlife 

BLM Scoping Questions: 

 What are the current conditions and extents of wildlife habitat in the project area?
 

 What are the seasonal patterns of wildlife use and movement in the project area?
 

 Are wildlife populations increasing or decreasing in the project area?
 

Scoping Comments: 

	 With regard to wildlife habitat fragmentation, analyze the project at a level that reflects full 

potential development of the area, rather than on a piecemeal basis to ensure that the consequences 

of full-field development are clearly understood before wildlife resources are committed. 

 Address loss of wildlife habitat and habitat effectiveness, fragmentation, effects to migration 

corridors, harassment of wildlife by increased traffic, noise, and illegal activities. 

 Evaluate where elk will be displaced to, and whether such habitat is suitable and/or herds will be 

tolerated by private landowners. 

	 Conduct raptor nest surveys and evaluate impacts to nesting. Establish mitigation such as seasonal 

timing restrictions, siting of facilities, and installation of artificial nesting platforms away from 

project disturbances and areas where they could impact Sage-grouse. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 Evaluate expected cumulative impacts to wildlife habitat and individual populations and herds 

relative to other energy development occurring in the area, particularly Atlantic Rim. 

	 Analyze impacts to each of three separate pronghorn herds, both direct and cumulative (instead of a 

regional or species analysis). Analyze impacts to individual herds of mule deer and elk, as well as 

three Sage-grouse management areas that overlay the project area. 

	 Evaluate impacts to mountain plovers. 

	 Use the lowest road densities possible to minimize habitat loss and disturbance by vehicles. 

	 Operators should fund necessary wildlife surveys exceeding those normally conducted annually by 

state and federal biologists. 

	 The EIS must address the impacts of oil and gas development on wildlife and wildlife habitat 

function, including: 

o	 the ecological needs of wildlife on a regional scale; 

o	 impacts on pocket gophers; 

o	 impacts on mountain plovers; 

o	 impacts on prairie dogs. 

o the dispersal or recovery of gray wolves in the southern Red Desert; 

 BLM must ensure full compliance with BLM Manual MS-6840.06.E (Special Status Species 

Management), including attention to ferruginous hawks, other raptors and sage-grouse. 

	 We urge that BLM protect more than “critical” big game winter ranges. 

	 We ask that the environmental analysis provide for wildlife diversity by protecting riparian areas 

and other special habitats, protecting certain species, maintaining connectivity between habitats, 

maintaining corridors, and assessing indirect and cumulative impacts. 

	 BLM should adopt the provisions of the WGFD recommendations on sustaining important wildlife 

habitats affected by oil and gas development. 

	 The EIS should analyze potential impacts to wildlife habitat, including big-game crucial winter 

range, sage-grouse, raptors, predators, and big game in general. 

	 Consider the impact of road building, increased human presence and disturbance, timber harvest, 

mineral exploration, grazing, etc. on wildlife. 

	 Protect all species of migratory birds, including Bald eagle. 

	 The project will be detrimental to the ability to sustain area wildlife. 

	 Natural gas development is estimated to span 30-50 years in Desolation Flats and Continental 

Divide/Wamsutter II, and this project will last as long if not longer. Where will wildlife go? 

	 The northern portion of the project area supports the only viable assemblage of native bluehead 

suckers, roundtail chubs, and flannelmouth suckers known to still exist in Wyoming. This portion of 

the stream provides preferred breeding habitat, and movement up or downstream is restricted by the 

combination of physical barriers and water temperatures. Any cumulative energy development 

activity that negatively affects the integrity of the watershed and overall stream health may 

jeopardize their future existence. An NSO restriction is recommended for surface gas development 

between the Continental Divide north of Muddy Creek proper and the Muddy Creek/Dry Cow 

Creek hydrographic divide located south of Muddy Creek and upstream of the large wetland 

complex. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

Special Status Species 

BLM Scoping Questions: 

 How much surface area will be disturbed and for how long? 

 What provisions for interim reclamation will be made?
 

 Which wildlife species of importance may be impacted by the proposal?
 

 Will any threatened or endangered species be affected by the proposal?
 

Scoping Comments: 

 The EIS must address the impacts on BLM sensitive plants. 

 Assemble regional habitat-use data from published data where available for T&E species and other 

key species. Include impacts of road density on local species, distance of road effects to determine 

the width of effect zones, and species dispersal distances to evaluate the size of core areas. 

 The following T&E Species, or species proposed for listing, may be present in the project area: 

Bald eagle (threatened; found throughout the state). Restrict activities within 1 mile of nests in open 

country year round. Limited disturbance home range buffer zone may extend outward in potential 

foraging habitat for 2.5 miles from the nest. 

Black-footed ferret (endangered; prairie dog towns). There may be impacts to two white-tailed 

prairie dog complexes in the project area where the species is found, and surveys may be 

recommended if complexes of greater than 200 acres are affected. 

Blowout penstemon (endangered; sand dunes south of Ferris Mtns). Surveys should be conducted in 

mid-June to early July when flowering occurs. 

Ute ladies’-tresses (threatened; seasonally moist soils & wet meadows below 7,000 feet). Surveys 

should be conducted. 

Colorado river fish: Bonytail, Colorado pikeminnow, Humpback chub, and Razorback sucker 

(endangered; downstream riverine habitat, Yampa, Green and Colorado). Formal consultation is 

required for projects that may lead to depletion of the waters including ponds, lakes, reservoirs, 

hydrostatic testing of pipelines, wells, dust abatement, diversion structure, and water treatment 

facilities. 

Include an estimate of the amount and timing of average annual water depletion, both existing and 

new; describe estimating methods, location of depletion, if and when water will be returned to the 

system, and what the depletion is being used for. 

Yellow-billed cuckoo (candidate). Provide status of the species in and near the project area. 

Sensitive species, as identified on the Wyoming Natural Diversity Database. 

Pygmy Rabbit. Encourage project planning measures that retain large tracts of suitable habitat and 

corridors to adjacent habitat. 

Greater Sage-grouse (species of concern). 

o	 Closely evaluate any activities that result in loss or degradation of sagebrush habitat. 

o	 Contact Wyoming Game & Fish to identify important habitats, and survey/map important 

habitats where local information is not available. 

o	 Evaluate long-term and cumulative effects on the species, since reclamation may not restore 

populations to pre-activity levels. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

o	 Unless site-specific information is available, manage habitat following Western Association of 

Fish and Wildlife Agencies guidelines. 

Mountain plover (species of concern). Develop protective measures with an assurance of 

implementation should they be found in the project area. 

	 Consider whether potential impacts to listed species on state and private lands will occur as a result 

of actions on BLM managed lands, and develop measures to avoid or minimize impacts. 

	 The EIS must address the impacts of oil and gas development on wildlife and wildlife habitat 

function, including:
 

o	 implementation of a conservation community “blueprint” for Sage-grouse and Sage-grouse 

habitat throughout the project area; 

o	 impacts on mountain plovers; 

	 BLM must analyze how ESA and BLM-sensitive species would be affected by failure to conserve 

white-tailed prairie dogs, including the impact on black-footed ferret recovery and on BLMSensitive and Colorado River Endangered fish species. 

	 Native fish species in the Muddy Creek drainage are considered sensitive (Status I Species) to both 

State and Federal agencies. Therefore, habitat function is to be maintained. WGFD’s Strategic 

Habitat Plan identifies the Muddy Creek watershed as the #2 habitat priority for both aquatic and 

terrestrial wildlife in most of Southwestern Wyoming. 

	 BLM must analyze how other ESA and BLM-sensitive species would be affected by the project, 

including BLM-Sensitive and Colorado River Endangered fish species. 

	 Baseline studies on pygmy rabbits and impact on this species should be included in the EIS. 

	 Full-field development will destroy habitat value for sage-grouse leks, hastening their listing under 

the Endangered Species Act. 

	 In addition to direct habitat loss for greater Sage-grouse, evaluate secondary disturbance to Sagegrouse in undisturbed habitats adjacent to the project area. 

	 Evaluate expected impacts and habitat avoidance by Sage-grouse due to structures (particularly
 

powerlines)
 

	 Consider development of artificial leks near existing roadside leks to attract grouse to safer areas. 

	 Identify and map all existing disturbances of Sage-grouse habitat near the project and evaluate the 

degree of existing habitat fragmentation, as well as how it would be accelerated by this proposal. 

Wild Horses & Burros 

A cumulative impact analysis is recommended examining regional effects to the area including South 

Baggs, Atlantic Rim, Desolation Flats, Pacific Rim, Table Rock, and Vermillion Creek natural gas fields, 

and the Black Butte Mine. Include the overpopulation of feral horses and nonstandard fences in the 

analysis of effects on wildlife. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 HUMAN ENVIRONMENT 

Visual Resources 

BLM Scoping Questions: 

 Will there be visual impacts from the project?
 

 Can visual impacts be mitigated to conform with the existing landscape and visual quality 

objectives
 

Scoping Comments: 

 The project will destroy natural vistas and open spaces. BLM should avoid development in areas 

where the impacts of development would be visible for long periods of time or from long distances 

 BLM must protect visual character and scenic resources, including protection from light pollution 

and impacts to the appearance of the night sky.. 

	 A sensitive landscape that warrants special protection for its visual quality is a “a small portion of 

the Red Lake Dunes Citizens’ Proposed Wilderness” located in the dune field immediately west of 

the gravel road leading northward to Hay Reservoir. 

	 Identify and set aside important scenic and undeveloped areas so that the public has a few
 

unimpaired lands left to visit after this project is underway.
 

	 The North Flattop unit is an area of high importance for visual resources that is not protected under 

the Great Divide RA RMP, that should be excluded from O&G development. Other such areas are 

Red Lake Dunes and Cyclone Rim (Class I). 

 Protect visual quality in a “5-mile buffer” associated with the Continental Divide Trail (Class I) and 

with the Cherokee and Overland trails (Class II). 

 The EIS should analyze the impacts to scenic quality from effects to visibility and of impacts to the 

landscape from drilling. 

Recreation 

BLM Scoping Questions: 

 How would the proposal affect recreation in the immediate and general areas?
 

 Are there opportunities to enhance recreational opportunities in and around the project area as a
 

result of the proposal?
 

Scoping Comments: 

	 Evaluate whether increased well densities and roads will further impact recreational use (including 

hunting). If there is any potential for closing public lands near gas company facilities, address it in 

the EIS. 

 Fragmented/shrinking habitat due to road development could increase grazing competition with
 

wild herds and also decrease hunting success and/or hunter numbers.
 

 Opposition was expressed to the implied notion of having industry enhance recreational
 

opportunities.
 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 BLM should explicitly address “unquantified environmental values” such as the value of the project 

area and nearby lands for primitive and unconfined recreation and for “simple open space values.” 

	 Map of recreational resources identifies two areas of “Citizens’ Proposed Wilderness” that
 

potentially affect the project area. These are associated with the Red Lake Dunes WSA and the 

Adobe Town WSA.
 

Cultural and Historical Resources 

BLM Scoping Questions: 

 Will there be impacts on historic and archaeological resources in the project area as a result of
 

development and operations?
 

 Are there any cultural resources located in the project area that would be eligible for the National
 

Register of Historic Places?
 

Scoping Comments: 

 Conduct thorough archaeological studies and provide mitigation to protect paleontological, historic, 

prehistoric, or cultural resources in the project area. 

 Give specific attention to historic trails in the area. 

 Give great consideration to the effects of further authorized development on visitors to historic trail 

corridors. 

 Work with recognized experts to prevent damage to historic trail ruts, considering the economic 

costs of damage. 

 Ensure that there is sufficient inventory of cultural resources in order to avoid resource conflicts. 

	 BLM must pursue consultation with Native American tribes and protect native sites, and must meet 

its Section 110 and Section 106 obligations and the requirements that it consult with appropriate 

Native American groups. 

Socioeconomics 

BLM Scoping Questions: 

 How would populations of Sweetwater and Carbon Counties be affected by the project? 

 How much income to Carbon and Sweetwater Counties and the region would be generated by the 

project? 

 How will the project affect the tax base of local government? 

 Will there be any impact to local social services, law enforcement, schools or other local community 

services as a result of the project? 

 Will there be an impact on housing costs in Rawlins, Wamsutter, and other Carbon and Sweetwater 

County communities as a result of the project? 

 What will be the impact of the project on the economies of Rawlins, Wamsutter and other 

Sweetwater and Carbon County communities? 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-11 
 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

Scoping Comments: 

	 BLM must estimate the amount of gas that is both technically and economically recoverable. 

	 Economically recoverable reserve estimates must include the costs of exploration, development, 

production, profit, transportation costs, non-market costs, off-site mitigation costs such as increased 

water treatment costs. 

	 Please complete a marginal revenue cost analysis of estimated gas production levels. Please 

compare and contrast the marginal revenues with the marginal costs for the full range of drilling 

levels. 

	 Socioeconomic impacts to surrounding communities should be assessed including labor 

competition, housing demand and government expenditures. 

	 Request that BLM’s socioeconomic assessment should follow the approaches set out in the scoping 

briefs “Socioeconomic Framework for Public Land Management Planning: Indicators for the 

West’s Economy” and “The Economic and Social Impacts of Oil and Gas Development.” 

	 BLM should utilize a Total Economic Valuation Framework for evaluating proposed oils and gas 

development projects. 

	 The scope of the BLM analysis should extend beyond the surrounding areas. 

	 BLM must recognize wilderness characteristics and other natural qualities as valuable resources that 

provide multiple uses for the public. 

	 Request that BLM fully consider the indirect role of wild lands in attracting non-recreational 

businesses and retirees. 

	 A full accounting of all hidden costs of oil and gas drilling is needed. Hidden costs include: 

o	 changes in direct use of lands within and adjacent to the analysis area, 

o	 changes in community conditions such as air water and noise pollution, 

o reductions in the value of the area for study of natural ecosystems,
 

o off-site environmental effects on other uses of the land,
 

o effects on biodiversity, effects on ecosystem services, effects on passive use. 

 The BLM should avoid IMPLAN or other input-output models that are grounded in economic base 

theory when estimating jobs and income for each alternative. We recommend that BLM use the EPS 

model developed by and available free from the Sonoran Institute. 

 The NEPA analysis should be based on reasonable (BLM) budget expectations, which should be 

clearly stated and the BLM must include a fiscal analysis of alternative implementation and 

mitigation costs. 

 To provide socioeconomic context, the BLM should examine historic trends in county income and 

employment, using the Sonoran Institute Economic Profile System. 

 Request that the agency identify all applicable federal state and local tax laws including exceptions 

and reductions and make realistic and accurate estimates of net tax revenues from oil and gas 

production, based on economically recoverable reserves and including the net environmental and 

community costs from drilling and production. 

 Estimate the socioeconomic costs to communities from oil and gas development. 

 Increased costs to private landowners and residents. 

 Increased costs to local governments. 

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APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 Economic instability and loss of economic diversity.
 

 Estimate and evaluate the environmental costs of oil and gas development.
 

 Bonding requirements for industry must be estimated and included in the analysis.
 

 BLM must include an analysis of the costs of implementing each alternative, including the cost of
 

mitigation measures. These costs must then be contrasted with the anticipated budget levels to 

assess the probability of mitigation measures being fully implemented. BLM should include a 

reasonable budget limitation and evaluate a set of management alternatives that are constrained by 

that budget level. 

 The costs of enforcement of environmental protection and mitigation requirements must be 

estimated and included in the NEPA analysis. 

 The project specific and cumulative effects of increased costs and decreased revenues on affected 

grazing operators should be assessed. 

 Recommend that the EIS include a full and thorough social and economic impact analysis including 

impacts to livestock grazing. 

	 The EIS should include an assessment of the potential for loss of environmental, historic and social 

values associated with livestock grazing and the importance of such losses to area residents and 

visitors. 

 BLM must address state and federal as well as local benefits associated with royalty payments and 

tax revenues derived from natural gas production associated with the CD-C project. 

 The benefits of increased supplies of natural gas to the consumer must be analyzed and discussed. 

 The EIS should contain a detailed analysis of the socioeconomic impacts and positive effects of the 

proposed action and alternatives for the State of Wyoming and affected counties and communities. 

 The local economy significance criteria should be discussed. 

	 The EIS should consider potential project effects on local communities including housing, schools, 

water and wastewater services, increased road traffic with associated dust and hazardous materials 

spill potential and easier human access to wildlife habitat with associated increased potential for 

wildlife disturbance. Methods to avoid or mitigate identified impacts should be discussed. 

	 The assessment should consider the effects of reasonably foreseeable development on area
 

communities.
 

Transportation 

BLM Scoping Questions: 

 Will motor vehicle traffic be associated with the proposed operation?
 

 How will employees, contractors, supplies reach the site?
 

 Will new roads need to be constructed?
 

 How will infill development affect existing transportation systems including highways, county
 

roads and project area transportation?
 

 Can transportation planning reduce and mitigate some of the impacts from further development?
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-13 
 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

Scoping Comments: 

	 Evaluate likely increases in subdivisions, sale of small private tracts, permanent roads, powerlines 

and fences resulting from this project, and the major negative impacts to all wildlife species in the 

project area. 

	 Generate infrastructure scenarios prior to field development, providing multiple road scenarios for 

potential infrastructure. Include both generous and conservative estimates of infrastructure 

construction, based on estimates of hydrocarbon resources for the field. Take particular care if 

unconventional or continuous-type deposits are involved. 

	 Reduce road density to create blocks of core habitat at a minimum distance from roads (.25 miles 

for bighorn sheep, pronghorn, and mule deer). Use the Society’s landscape fragmentation metrics to 

guide management decisions regarding transportation routes for other wildlife species, with the 

goals of reducing road density and edge effects and increasing core areas to provide greater habitat 

security. 

	 Establish priorities and best management practices to close and reclaim roads and other routes. 

	 Create a responsible transportation plan, incorporating detailed guidance from NEPA and FLPMA, 

specifically: 

o	 Consider the environmental consequences of the proposed action based on accurate scientific 

information of high quality [40 CFR 1500.1(b)], and conduct a high-quality analysis of the 

information collected. 

o	 Take any action necessary to prevent unnecessary or undue degradation of the lands and 

minimize adverse impacts on the natural, environmental, scientific, cultural, and other 

resources and values (including fish and wildlife habitat) of the public lands involved. 

(FLPMA). 

o	 Following selection of an alternative, continue to monitor the plan, and make appropriate 

revisions to ensure it is meeting its objectives. 

	 Use of existing roads and pipeline corridors should be maximized, and extraordinary steps taken 

where new pipelines or roads cross the trails.
 

	 Use BMPs to locate roads, pipelines, and wells. 

	 Include the amount of aggregate needed to support anticipated road development in the analysis. 

The division is concerned about the availability of aggregate from currently permitted operations 

and the possible need for new sources. 

Noise 

BLM Scoping Questions: 

	 How much noise will be associated with the proposed project and what are those noise sources? 

	 Will sound effects be audible for specific distances from certain points. 

	 How will topography affect audibility distances? 

Scoping Comments: 

	 The environmental analysis should address issues related to noise in terms of remoteness and
 

quietness.
 

A-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 MANAGEMENT ENVIRONMENT 

Lands and Realty 

BLM Scoping Questions: 

 What is the current and planned land use policy for the project area?
 

 What would be the impact on local land use patterns in the project area?
 

 How does the “checkerboard” surface ownership created by the Union Pacific Land Grant affect the
 

EIS analysis and possible future gas development? 

Rangeland Management 

BLM Scoping Questions: 

 How much surface area will be disturbed and for how long? 

 What provisions for interim reclamation will be made?
 

 How will noxious weed populations be monitored, and controlled?
 

Scoping Comments: 

	 Consider the feasibility of supplemental feeding of livestock on permitted grazing land in areas 

where road construction will decrease available forage.
 

	 Fragmented/shrinking habitat due to road development could increase grazing competition with 

wild herds. Consider supplemental feeding of livestock or other mitigation measures if necessary to 

minimize impacts to rangeland. 

 The Federation supports water development projects if the water is of high quality. Produced water 

could be pumped to stock ponds and reservoirs and new storage reservoirs created. 

 Consider impacts to rangeland for wildlife as well as domestic animals. 

 The scoping notice did not identify grazing or rangeland management as significant issues, and this 

is a serious and disrespectful omission. 

 Road traffic in the Rawlins FO area has led to livestock deaths and injuries from collisions. 

 The introduction and growth of noxious weeds has weakened and killed livestock and crowded out 

forage. 

 The significant increase in road dust has diminished the palatability and nourishment of forage. 

 Damaged cattle guards, cut fences, and unlocked gates have raised unnecessarily repair costs and 

diverted labor to search for lost livestock, some of which were never found. 

 Loss of water from artesian and flowing wells has weakened livestock health, reduced weight gain 

and available forage, induced weeds. 

 Reclamation has been poor, resulting in further loss of forage. 

 Potential conflicts should be characterized as “probable,” not “possible” as currently written. 

 Data from the Fremont County study conducted by the University of Wyoming should be included 

in the EIS. 

 The BLM, grazing permittees, and proponent should work cooperatively throughout the life of the 

project to make site-specific, case-by-case decisions. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-15 
 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 Research and monitoring conducted by the operators should include movement of livestock to an 

open allotment or pasture, purchase of hay in lieu of allotment use, monitoring of development 

impacts, including use of the Wyoming Rangeland Monitoring Guide of August 2001, construction 

of water and range improvements on either public or private land, purchase or lease of additional 

grazing land to replace lands lost to grazing, and reimbursement to producers for loss of AUMs and 

pastures. 

 Analyze the impacts of the loss of open space, scenic vistas and historic rural landscape as related to 

loss of grazing lands. 

 The impact of this project upon food and habitat for domestic animals deserve the same study and 

documentation as for fish and wildlife. 

	 Include the positive effects of livestock grazing on the environment and as a tool to achieve 

environmental objectives, and the impacts of the project on limiting the ability of livestock grazing 

to achieve positive effects. 

	 Evaluate how development of additional wells would affect distribution of livestock and feral
 

horses, and effects of changes to grazing on sage-grouse, mountain plover, and big game.
 

	 Address worker housing, the necessity to commute, and the resulting heavy deposition of dust on 

vegetation and adjacent habitats. Evaluate and mitigate negative effects and loss of AUM’s/wildlife 

forage. 

Areas of Critical Environmental Concern 

 Give priority to the designation and protection of ACECs for wildlife. 

 Designate ACECs in areas of crucial winter range and at pinch points of migration routes, with 

management prescriptions that include no creation of new routes or expansion of existing routes, no 

new leasing unless designated NSO, no new energy development, no cross-country travel, limitation 

of off-road vehicles to designated routes, and closure of unnecessary routes. 

 Red Lake Dunes and Chain Lakes proposed ACEC should be withdrawn from drilling 

Wilderness 

 Wilderness characteristics and other natural qualities must be recognized as a valuable resource. 

General and Administrative Issues 

	 BLM should not approve the project prior to revision of the Rawlins RMP so that the project can be 

pursued under the framework of an updated RMP. 

	 The Rawlins Field Office (RFO) is preparing a revision to its RMP that will assess options for 

preservation of migration corridors and environmentally sensitive areas, including new technologies 

and other impact-reducing measures. A revised scoping notice for Creston/Blue Gap II removed the 

requirement that the RMP be complete before a decision is issued for C/BGII; this violates the 

NEPA process and will delay implementation of RMP decisions, likely allowing more lenient 

mitigation measures for C/BGII. 

	 The proponent is bound by stipulations in the Great Divide Resource Management Plan, and in
 

future by the Rawlins Resource Management Plan.
 

A-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 The ROD for this EIS will be held up indefinitely because of delays in preparation of the Rawlins 

RMP FEIS. 

 It is unwise to combine the Creston-Blue Gap and Continental Divide projects because one is an 

infill project in a largely industrial area and the other includes vast stretches of undeveloped lands. 

 This proposal is consistent with the Energy Policy Act of 2005. 

 Comment indicated concerns regarding multiple-well EAs/EISs. 

 Include PacifiCorp in the process to ensure that their rights to site, construct, operate, and maintain 

their facilities are considered and protected. 

 Work cooperatively with Wyoming Game and Fish, local government, and non-government 

organizations 

 Grant the Alliance for Historic Wyoming “interested party” status for Section 106 procedures for 

this EIS. 

 Hold multiple public hearings. 

 Judging from the list of issues, concerns, and opportunities issued by BLM to date, we are 

destroying what makes Wyoming Wyoming. 

 Endless pollution from drilling has cost $70 million in cleanup costs to taxpayers 

 No drilling should be allowed on BLM land unless an insurance policy bond is posted for cleanup 

costs 

 The entire American public is skeptical of our energy policy and secret meetings. 

 The rate of development in the eastern Red Desert is completely out of control, following on the 

heels of Atlantic Rim and soon to be followed by Continental Divide. 

	 Increased gas supplies from this area, as well as Wamsutter, will be necessary within the next two 

years to ensure that the Kinder-Morgan/Sempra pipeline to Ohio carries Wyoming gas rather than 

from other states. 

	 The writers support the project and development of the EIS. 

Scoping and Approach 

	 BLM should define the scope of the environmental analysis to include analysis of the cumulative
 

effects of actions/projects that have impacts in common with those resulting from natural gas 

development.
 

 BLM should consider, analyze, and wherever appropriate, facilitate, international efforts to prevent 

environmental decline. 

 BLM cannot define the purpose and need for the project as just to allow natural gas to be developed; 

it must also include strong environmental protections as at least a co-equal purpose and need. 

 BLM must establish the baseline condition or all resources in the area in order to evaluate 

environmental conditions and impacts in an informed manner. 

 Require incorporation of all NEPA policies and goals 

 BLM should “infuse” the goals and policies of the National Environmental Policy Act into the 

environmental review and decision document. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-17 
 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 Generate landscape metrics for all infrastructure, including density, infrastructure effect zones, and 

core areas. Metric parameters and evaluation of results should be relevant to ecological conditions, 

species present, and human use of the landscape. Integrate results into management plans, 

	 We urge BLM to require that development activities not cause unnecessary or undue degradation. 

	 Notify all lessees of their responsibility to comply with federal and other applications regardless of 

land or mineral ownership. 

	 If BLM, surface owners, and lessees agree, non-BLM lands can be included in section 7 

consultation on federal lands. 

	 Specific management actions like the proposed project must be done pursuant to multiple use and 

sustained yield principles. 

	 The environmental analysis and decision document should emphasize resource and ecosystem 

protection, which will best ensure that future options are retained. 

	 No new project area disturbance should commence prior to completion of formal consultation under 

Section 7 of the ESA, preparation of a BA. 

	 Trade approved APDs for a new APD. 

	 Provide access to State mineral leases. 

	 Continue development on fee lands when access across adjoining BLM-administered land has 

already been approved. 

	 Permit rights-of-way (pipelines) for previously approved projects. 

	 Suspend operations on undeveloped federal leases. 

	 Permit drainage wells for Federal minerals on a case-by-case basis. 

	 If surface disturbance and other impacts can be shown to be below that analyzed in the EIS, 

additional wells may be permitted. If reclamation activities can result in reduced surface impacts to 

a point below that analyzed in the EIS, additional wells may be permitted. 

	 Set a schedule for completion of the EIS and adhere to it, identifying and explaining the reason for 

any delays to the National Energy Policy Office. 

	 Analysis completed for previous projects in this area will provide opportunities to reduce the time 

and cost required to prepared this EIS. Analysis from other documents should not be duplicated. 

	 Analyze the impacts associated with the proposed action only. 

	 Honor the MOU with the Wyoming State Land Office concerning access to state lands and honor 

private property rights. Make a statement in the EIS addressing BLM’s right to restrict access to 

private lands beyond a customary 30-day right-of-way application period. 

	 Consult with and use BLM’s Reservoir Management Group to assess the requirements to adequately 

drain natural resources and prevent waste. 

	 Planned or phased development of the area is not feasible unless one operator controls leases on the 

entire area because it could create a taking by BLM through restriction of development of a 

leasehold. 

	 Consider cumulative impacts of this and other area projects. 

	 A cumulative impact analysis is recommended examining regional effects to the area including 

South Baggs, Atlantic Rim, Desolation Flats, Pacific Rim, Table Rock, and Vermillion Creek 

natural gas fields, and the Black Butte Mine. 

A-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 A landscape-level analysis should consider direct, indirect, and cumulative impacts of this larger 

combined project. 

 Consider adhering to multiple use under FLPMA. 

 Use drilling rigs powered by electricity, natural gas, or biodiesel rather than conventional diesel. 

 Overall comments focus on harmonious, coordinated resource management that considers the 

relative values of resources. 

 Any development should be slow and should only occur after reclamation of existing disturbances. 

 Development in Wamsutter makes it that much more important to protect remaining pristine 

landscapes like Adobe Town, Jack Morrow Hills, and Wild Cow Creek. 

 No drilling should be allowed the eastern Red Desert 

 No coalbed methane development due to as-yet unknown long-term consequences 

 All support facilities (roads, power lines, pipelines, and well site facilities) should be included in the 

APD and Sundry Notice permit process. 

 New categorical exclusions can only be legally utilized following an analysis of whether 

extraordinary circumstances (per NEPA, the ESA, NHPA, etc.) may prevent their application. 

	 The NEPA analysis should be based on reasonable budget expectations to ensure that mitigation
 

measures and resource protection will be funded, and BLM should include a fiscal analysis of
 

alternative implementation and mitigation costs.
 

	 Given their stewardship responsibilities, governments should encourage or undertake activities that 

protect the environment and discourage or prohibit those that do not. It is also appropriate for 

government to own and use land and water resources to protect the environment and to support 

others in doing the same. 

	 Government should continually seek to improve the efficiency of its environmental and resource
 

management programs without compromising its responsibilities (a mixture of regulations,
 

incentives, and public ownership of resources). It should aim to bring about as high a level of
 

environmental quality for a given expenditure.
 

Alternatives Development 

	 IM 2005-047 provides guidance for NEPA compliance in oil and gas that supports the Energy
 

Policy Act of 2005 and may not be valid under existing law. Specific concerns include the
 

development of alternatives that increase/accelerate development and use of new categorical
 

exclusions.
 

 We ask that at least one alternative fully explore phased development and directional drilling to the 

maximum extent possible. 

 Consider an alternative that would only allow minimal surface disturbance. 

 We ask BLM to consider an alternative that would only allow development to occur from existing 

oil and gas well pads, with maximum use being made of directional drilling technologies. 

 Similarly, we ask BLM to consider an alternative that would not allow for any additional road 

construction. 

 APDs that have expired will not be extended so that pending APDs may be permitted. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-19 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 Alternatives must consider geological, technical, and other issues such as correlative and leasehold 

rights. 

 Any constraints in the alternatives should also evaluate the additional difficulties they may generate. 

Directional Drilling 

 Directionally drill wells from existing well pads 

 Evaluate the effect of intense development and high-density gas wells on the Department’s 

management of Chain Lakes Wildlife Habitat Management Area, including the feasibility of using 

directional drilling in wetlands and sensitive areas associated with the lakes and use of artificial 

pads or pontoons to access development sites. 

 Directional drilling is appropriate in some areas but should not be mandated for areas where it is not 

appropriate. Because it increases both cost and risk, directional drilling should be considered only at 

the site-specific analysis level. 

 Use directional drilling and cluster up to 32 wells per pad and avoid intrusion into sensitive wildlife 

habitats. 

 At the very least, directional drilling using 32 wells per pad should be required. 

 Require the industry to cluster wells, up to 64 per pad, to minimize surface impacts. 

 If directional drilling is to be allowed, why not specify it as the preferred method of extraction? It is 

a proven, economical technology that minimizes damage.
 

 If directional drilling is not considered a “reasonable alternative” please be specific as to the
 

meaning of that phrase in the context of the project and its environmental impacts.
 

 Multiple wells should be drilled at a single location when feasible, and wildlife disturbance
 

minimized (e.g. by automated pumping facilities).
 

 Include mitigation such as directional drilling and BMPs in all alternatives.
 

 Require directional drilling and cluster development
 

 Address the potential for directional drilling to minimize habitat fragmentation;
 

 Directional drilling should be used to access subsurface gas leases from outside the NSO area.
 

Mitigation and Monitoring 

 Mitigation plans should include goals and objectives, methodologies, time frames for
 

implementation, success criteria, monitoring, and a contingency plan if unsuccessful.
 

 Apply a standard NSO stipulation to all riparian zones and a 500-ft corridor from the outermost
 

limit of the riparian habitat.
 

	 During pipeline construction, avoid stripping riparian canopy or stream bank vegetation if possible. 

Crush or shear streamside woody vegetation rather than completely removing it. Revegetate 

immediately after stream bank crossings are completed. 

 BLM must ensure that the impacts of any coalbed methane development are mitigated. 

 Address the exception process for seasonal wildlife stipulations, which are expected to be numerous 

on a project this size. Note that additional data needed to accommodate industry requests should be 

funded by industry. 

A-20 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

	 Consider lease and development stipulations to protect critically important wildlife and their 

habitats. 

	 Consult with Wyoming Fish and Game and USFWS early in the process to protect critical habitat. 

	 Discuss and evaluate monitoring data from existing gas development before developing habitat 

protection strategies and mitigation measures. 

	 Establish zones of habitat protection of areas of high wildlife value and develop habitat 

improvement needs in other areas. 

	 With regard to wildlife habitat fragmentation: 

o	 Develop a transportation plan to reduce access roads and traffic. 

o	 Bury power lines within the right-of-way to avoid impacts to raptors and other bird species. 

o	 Power generators by natural gas to reduce toxic emissions, and fit compressors with highquality mufflers to keep noise to a minimum 

o	 Enforce any commitments agreed to by operators during the APD. 

	 Establish seasonal stipulations on development and production activities in big game habitats, and 

treatment or modification of remaining habitat or intervening fences to increase the amount or value 

of crucial winter habitat. 

	 Address mitigation for short-term and long-term impacts to habitat, and exclusion of waivers for 

wildlife habitat mitigation. 

	 Develop and implement route closure and reclamation plans to restore and maintain critical biggame habitat and linkages: 

o	 Mule deer: increase the amount of core area greater than 1,542 feet from route within crucial 

winter range and along migration corridors. 

o	 Pronghorn: Increase the amount of core area greater than 3,168 feet from a route and reduce 

route densities below one mile per square mile within crucial winter range and along migration 

corridors. 

o	 Elk: Reduce route densities below one mile per square mile within crucial winter range and 

along migration corridors. 

o	 Prohibit drilling and surface occupancy in big-game wintering areas between November 5 and 

April 30 

o	 Implement seasonal traffic restrictions on all roads within 656 feet of Sage-grouse winter 

habitat (9:00 a.m. to 5:30 p.m., mid-November through March) within 3 miles of breeding and 

nesting areas (9:00 a.m. to 5:30 p.m., March through mid-May), and in brood-rearing areas 

(900 a.m. to 5:3 p.m., June through mid-July). Impose a speed limit of 30 miles per hour during 

non-restricted hours. 

o	 Combine these species-specific recommendations with more general provisions to benefit all 

wildlife species in the area such as: 

 planning for staged development of energy resources 

 restricting new roads and energy development, especially within crucial winter range and at 

pinch points of migration routes 

 allowing few exceptions to temporary occupancy restrictions 

 imposing rigorous standards for ecological restoration of closed routes 

 for all new roads that are built, following the road construction guidelines of the Wyoming 

Game and Fish Department to minimize the effect of routes on wildlife 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-21 
 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

 including clear enforcement mechanisms to minimize impacts to wildlife 

 continuing to research the effects of the transportation network on wildlife species and 

using this knowledge in adaptive management. 

	 Develop a clearly defined management plan to protect the grouse population and monitor the 

success of on-site and off-site mitigation. 

	 Recommend NSO designation for Sage-grouse breeding habitat between March 1 and June 30 

annually and no project-related disturbance from November 15 through March 14. 

	 Require NSO protections within miles of Sage-grouse breeding leks. 

	 Consider noise mitigation alternatives such as seasonal timing stipulations, or modifying or 

enclosing compressors to minimize or eliminate loud, continuous noise during strutting periods 

from March 1 through May 20 each year. Avoid noise-generating activities from 6 PM to 9 AM 

within 2 miles of strutting grounds. 

	 Average nose mitigation levels should be attained no more than 200 meters from the noise source. 

	 Mitigation should include a 11⁄4-mile protection buffer and a 2-mile seasonal protection for the 

duration of the breeding season. 

	 Identify mitigation to protect nest sites and nesting pairs. Consider construction of artificial nesting 

poles. 

	 Include “no fencing” mitigation for roads and facilities that block pronghorn migration. Consider 

the possibility that pronghorn will trail along plowed access roads during periods of deep snow, and 

consider plowing escape ramps off roadways. 

	 Maintenance personnel should visit wells at midday to reduce harassment when seasonal 

stipulations are in effect. 

	 Establish mitigation to prevent exceedance of average noise standards so that courtship season is not 

disrupted. 

	 The EIS must address: 

o	 the extent and mitigation required for sagebrush habitat; 

o	 the mitigation standards for crucial winter range; 

o	 the use of 1-mile buffers around ferruginous hawk nest sites and burrowing owl nests; 

o	 implementation of a conservation community “blueprint” for Sage-grouse and Sage-grouse 

habitat throughout the project area; 

 Screens should be fitted to burners on production facilities to prevent songbird deaths 

	 The overall scale of the project makes serious adverse impacts inevitable for wildlife, fisheries, and 

recreational opportunities. The following restrictions are requested on all development in the project 

area: 

o	 A minimum of 95-percent flareless completion on all wells 

o	 Directional drilling used to its full extent to reduce footprint and habitat fragmentation 

o	 Remote monitoring of condensate tanks 

o	 Bus crews rather than individual trips 

o	 Monitor and police traffic during critical winter range periods 

o	 Cluster well pads 

A-22 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX A—SUMMARY OF SCOPING COMMENTS 

o	 Intensive mitigation to reduce noise and light pollution affecting Sage-grouse during strutting 

and parturition 

o	 Dust abatement 

o	 A minimum 3:1 ratio for off-site mitigation work to compensate for habitat fragmentation 

o	 Reclamation with a forb/shrub mixture consisting of native plants and grasses, rather than the 

BLM grass mixture. 

	 Monitor and analyze habitats surrounding the project area to reevaluate habitat protections such as 

the width of buffer zones, to provide suitable habitat as development proceeds. 

	 Incorporate wildlife monitoring and research projects, funded by the operators. 

	 Apply any stipulations only where least restrictive and absolutely essential, and then only after they 

have been peer reviewed. 

	 COAs for directional drilling in sensitive areas should require BMPs in accordance with IMI2005­

247 and IM2004-194, and the Gold Book, including but not limited to: 

o	 ACECs 

o	 lands with wilderness characteristics and sensitive or important wildlife habitat 

o	 closed-loop (pitless) drilling to help protect soils and water 

o	 requiring maximum use of existing roads 

o	 drilling multiple wells from a single pad 

o	 centralizing production facilities to reduce surface disturbance 

o	 noise reduction techniques and designs 

o	 wildlife monitoring 

o	 interim restoration to ensure lands are returned to their natural condition as soon as possible. 

o	 Collect baseline data and fund long-term monitoring. 

	 The Red Lakes Dunes citizen-proposed wilderness and other lands with wilderness characteristics 

should be inventoried and protected using VRM Class I or II designation, NSO limitations, and 

application of other BMPs. 

	 Include an aggressive noxious/invasive species control program (to protect forage). 

	 Attempt to mitigate vehicle-caused livestock losses due to increased vehicle traffic. 

	 Consider mitigation measures to prevent harm to agricultural water uses, including a detrimental 

drop in the water table. 

	 Require “green completions” for each new well and prohibit pit flaring during completion and 

fracking. 

	 Cease building new roads when maximum road densities are reached, until at least an equal amount 

of old roads are closed. 

	 Close and reclaim roads to dry well sites, completed wells, and where redundant or unnecessary. 

	 Address the use of on-site and off-site mitigation. 

	 Impose speed limits on heavily traveled roads where big game road kill is a concern. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 A-23 
APPENDIX B: PLAN OF DEVELOPMENT 

Table of Contents 

Introduction ............................................................................................................................. B-1 

Section 1 General Project Description ........................................................................... B-3 

1.1 Project Overview ............................................................................................... B-3 

1.2 Summary of Surface Disturbance ...................................................................... B-6 

Section 2 Pre-Construction and Site Layout ................................................................. B-8 

Section 3 Construction Activities ................................................................................... B-9 

3.1 Roads ................................................................................................................. B-9
 

3.2 Well Pads ........................................................................................................... B-9 

Section 4 Drilling and Completions............................................................................... B-16 

4.1 Drilling............................................................................................................. B-16
 

4.2 Materials Management .................................................................................... B-17 

4.3 Solid and Hazardous Waste ............................................................................. B-17 

4.4 Completions and Testing ................................................................................. B-17 

4.5 Interim Reclamation ........................................................................................ B-18 

Section 5 Production and Maintenance ........................................................................ B-20 

5.1 Well Production Facilities ............................................................................... B-20 

5.2 Pipelines........................................................................................................... B-20 

5.3 Compression, Gas Treatment, and Ancillary Facilities ................................... B-21 

5.4 Produced Water Disposal................................................................................. B-21 

5.5 Maintenance..................................................................................................... B-21 

5.6 Workovers........................................................................................................ B-22 

5.7 Geophysical Operations ................................................................................... B-22 

Section 6 Reclamation and Abandonment.................................................................... B-23 

Section 7 Operator-Committed Practices ..................................................................... B-24 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-i 
APPENDIX B—PLAN OF DEVELOPMENT 

List of Tables 

Table B-1. Preliminary Estimate of Surface Area Disturbance .......................................................... B-7 

List of Maps and Figures 

Map B-1. Continental Divide-Creston Natural Gas development Project ........................................ B-5 

Figure B-1. Typical single well pad layout, example 1 ..................................................................... B-10 

Figure B-2. Typical single well pad layout, example 2 ..................................................................... B-11 

Figure B-3. Typical CBNG well site layout ...................................................................................... B-12 

Figure B-4. Typical multiple well pad layout, example 1 ................................................................. B-13 

Figure B-5. Typical multiple well pad layout, example 2 ................................................................. B-14 

Figure B-6. Well pad after interim reclamation................................................................................. B-19 

B-ii Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX B—PLAN OF DEVELOPMENT 

INTRODUCTION 

The Continental Divide-Creston (CD-C) Operators submitted their Plan of Development (POD) for the 

CD-C project to the BLM in September 2006. The POD was subsequently revised in late 2007 to reflect a 

reduction in plans for coalbed natural gas (CBNG) development within the project area. The original POD 

had said that potentially 500 to 900 of the proposed 8,950 wells could be CBNG wells. The 2007 revision 

reduced that amount to “up to 500” CBNG wells. The 2007 version of the POD is the one reproduced in 

this appendix. 

Since the submittal of the revised 2007 POD, other changes and clarifications have been made to the 

Operators’ development plans. Although no formal revision of the POD has been made, the changes have 

been incorporated into Section 2.2.1 of the CD-C Environmental Impact Statement (EIS), The Proposed 

Action. The changes were most often made because of advances in drilling technology since the project 

was originally proposed or because the analysis of project impacts necessitated a more detailed definition 

of the Operators’ plans to adequately assess the effects. The changes occurred over the five years between 

2007 and 2012 and were generally evolutionary in the way they developed, with frequent emails and 

phone conversations discussing the changes before a decision was made to alter the development 

proposal. 

The Operators have agreed that the following descriptions of those changes and clarifications accurately 

reflect their intent and the POD is hereby amended as follows: 

1.	 Number of days required to drill a well. The POD said that drilling each gas well “will take about 

10 to 20 days” and that completion and testing operations typically will “require approximately 10 

to 20 (up to 30) days.” Given the improvements in drilling technology, the drilling time for each gas 

well, as described in Section 2.2.1.2 of the EIS, Drilling and Completion, has been reduced to 

“about 7 to 10 days.” The description of the time for completion and testing operations has been 

changed to “approximately 10 to 20 days.” 

2.	 Number of drill rigs active in the project area. The POD anticipated that the number of rigs 

necessary to achieve development objectives “will range from about 34 to 70 rigs at any particular 

time.” As described in Section 2.2.1.2, Drilling and Completion, the Operators have reduced that 

count to “up to 25 rigs at any particular time,” largely because the time needed to drill a well has 

decreased. 

3.	 Compression and gas treatment facilities. The Operators estimated in the POD that “one large 

central pipeline compression facility” may be required for the project and that “as many as ten 

additional compressor sites” and “ individual well site compression” as needed would be added to the 

existing infrastructure. They also said that “Compression requirements and associated horsepower 

estimates will be developed in association with the air quality analysis.” In addition, “It is anticipated 

that two or more central gas processing/stabilization facilities will be needed.” 

After considerable analysis and discussion, rather than trying to estimate the breakdown between 

the number, type, and size of compression facilities that would be needed, the Operators 

summarized compression needs in a single metric, the total amount of horsepower (hp) that would 

be required for future production. Section 2.2.1.5 of the CD-C EIS, Compression, Gas Treatment, 

and Ancillary Facilities, now states that an estimated 24,936 hp of additional compression may be 

needed as the project is developed for dedicated compressor sites and for additional compression at 

well sites. 

In addition, the number of new central gas-processing/stabilization facilities has been reduced from 

two to one. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-1 
 

APPENDIX B—PLAN OF DEVELOPMENT 

4.	 Sources of water used for project development. The POD describes the use of approximately 

20,000 to 30,000 barrels of water per well for drilling operations (Section 4-1 of the POD), 

approximately 4,000 to 12,000 barrels of water for completion and testing operations (Section 4-4), 

and approximately 2,700 gallons of water to test each mile of four-inch gas pipeline (Section 5-2). 

This “water will come from existing and new water supply wells within the project area, as well as 

from produced water sources which will conserve fresh water aquifers. . . .Water from reserve pits 

may be transferred and used for drilling.” (Section 4-1) 

The POD does not mention the use of any surface water and subsequent discussions with the 

Operators indicated that it was their intention that the statements in the POD were meant to exclude 

the use of any surface water. 

5. Use of fresh water. Section 4-1 of the POD states, “Fresh water will used for drilling the first 5,000 

to 7,000 feet of each gas well” and then references other uses of fresh water, including in Section 4-

4, Completions and Testing. The Operators have clarified that only fresh water can be used when 

drilling surface casing by regulation. However, other processes may not involve the use of fresh 

water but rather the re-use/recycling of water depending on the quality of that water and the planned 

use and regulatory requirements. 

6.	 Disposal of produced water from CBNG wells. Section 5.4 of the POD describes the process for 

disposal of produced water from CBNG wells, water that could be produced in volumes of 500– 

1,000 barrels per day per well. The volume of water produced in CBNG development is normally 

much greater than the amounts produced with conventional gas production. CBNG-produced water 

might “be stored on-site in a lined pit or storage tank, or water-collection lines might be installed to 

transport water to a water-treatment facility, evaporation ponds, injection wells, subsurface drip 

areas and/or approved discharge points.” The actual volumes produced and the methods by which 

the produced water would be managed are greatly dependent on the site-specific development 

proposals. For that reason, the BLM decided that although the POD for the CD-C project described 

the potential for surface discharge of CBNG-produced water, such disposal for any CBNG 

development within the CD-C project would be treated in a separate NEPA analysis. When the 

BLM receives site-specific CBNG proposals in the CD-C project area, the proposals, including the 

treatment of produced water, will be analyzed in a separate NEPA document at that time. 

7.	 Disposal of produced water from conventional wells. Section 5.4 of the POD also describes the 

process for disposal of produced water from conventional wells, water that would be produced 

averaging 18 barrels per day per well. This water would be “disposed of via subsurface injection, 

surface evaporative pits, or will be used for potential beneficial use (i.e. drilling operations).” The 

POD does not mention the surface discharge of water produced from conventional drilling. 

Subsequent discussions with the Operators clarified that the statements in the POD were meant to 

indicate that the Operators had no plans for the surface discharge of produced water from 

conventional wells as a method of disposal. 

8.	 Water used for dust abatement. The POD does not specifically describe the process of dust 

abatement, how much water might be used in the process, or where the dust abatement water would 

be sourced. Discussions with the Operators clarified that the 20,000 to 30,000 barrels of water per 

well for drilling operations described in Section 4-1 would include all water used for dust 

abatement. As described in Item 4 above, none of that water would come from surface sources. 

B-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 1. pROJECT dESCRIPTION 

 

 

 

APPENDIX B—PLAN OF DEVELOPMENT 

1. General Project Description 

1.1 PROJECT OVERVIEW 

BP America Production Company and other operators (identified herein as the “Operators”) propose to 

develop natural-gas resources within the existing Continental Divide and Creston Blue Gap natural gas 

fields, located in Carbon and Sweetwater counties, Wyoming. The project, known as the Continental 

Divide-Creston Natural-Gas Development Project, involves approximately 1.1 million acres in an area 

with a “checkerboard” pattern of surface ownership. The Bureau of Land Management (BLM), the State 

of Wyoming, and private owners issued the oil and gas leases covering these lands. The Rawlins Field 

Office (RFO) manages BLM surface lands and the federal mineral estate in the Project Area, which is 

shown on Figure 1. 

Oil and gas extraction in the Project Area is guided by relevant programmatic NEPA actions including the 

Great Divide Resource Management Plan (1990), and the decisions made in applicable project-specific 

BLM NEPA documents, including the Continental Divide/Wamsutter II Natural Gas Project and the 

Creston/Blue Gap Natural Gas Project. The BLM operates in accordance with the Federal Land Policy 

and Management Act of 1976 (FLPMA), which mandates that the BLM consider multiple uses for the 

lands it administers. FLPMA specifies that the BLM consider the land’s inherent natural resources as well 

as its mineral resources when making land management decisions. The BLM’s responsibility extends to 

environmental protection, public health, and safety associated with oil and gas operations on public lands. 

Mineral leasing decisions made by the BLM result in a contractual commitment from the United States to 

allow for exploration, development, and operations by the Operators in accordance with stipulations and 

restrictions incorporated within its leases. Lease rights include the right to occupy and use as much of the 

surface as is reasonably necessary to explore, develop, operate, and produce the subsurface oil and gas 

resources. The Operators understand that the decision that will result from NEPA analysis of this 

proposed project will pertain only to those areas in the Project Area where there are federal surface and/or 

federal minerals. The Operators recognize that the State of Wyoming and other local governmental 

agencies also have authority over various aspects of oil and gas development in all or portions of the 

Project Area. 

Collectively, the Operators propose to drill approximately 8,950 wells in addition to the wells that 

currently exist in the Project Area. Up to 500 of the proposed wells could be coalbed natural gas (CBNG) 

wells. The Operators anticipate drilling infill wells at potentially up to 40 acres per downhole well bore. 

The Project Area contains several units in addition to non-unitized lands. The total number of wells 

drilled will depend largely on factors outside of the Operators’ control that affect the ability to adequately 

drain the reservoir, including geologic characteristics and reservoir quality, appropriate engineering 

technology, economic factors, commodity prices, availability of commodity markets, and lease 

stipulations and restrictions. 

Based on current reservoir and well performance information, most gas wells will be completed in the 

Almond Formation (Mesa Verde Group); however, secondary reserves may be encountered in other 

formations (e.g. Lewis, etc.) for the natural gas wells. The CBNG development will primarily target 

formations such as the Fort Union (Big Red Coal) and secondary reserves may be encountered primarily 

in the Wasatch, Frontier, and Lance formations. 

This proposal assumes that the gas wells may be drilled conventionally, i.e., with a vertical well bore on a 

single pad, or with multiple directional well bores from a single pad. The gas resource is primarily 

conventional natural gas, however, the project also includes development of CBNG. Directional drilling is 

not being proposed by the CBNG operators. All proposed wells are anticipated to be drilled during an 

approximate 10 to 15 year period after project approval. Although actual operations are subject to change 

as conditions warrant, the Operators’ long-term plan of development is to drill additional wells at the rate of 

approximately 600 wells per year or until the resource base is fully developed. The average life of a well is 

expected to be 30 to 40 years for both the conventional gas and CBNG development. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-3 
 

 

 

APPENDIX B—PLAN OF DEVELOPMENT 

The facilities required by the project may include roads, gas, water, and condensate gathering pipelines, 

overhead and buried powerlines, production facilities (separation, metering, treating, fluid storage, 

compression, artificial lift, etc.), disposal well and/or surface disposal facilities, equipment storage 

facilities,and other associated facilities. In general, gas will be transported via subsurface pipeline to 

centralized compression and treatment facilities although some well site compression may be included on an 

as-needed basis. Produced water will be transported by truck to water disposal wells or evaporation ponds, 

or by pipeline to treatment facilities and/or discharge points. CBNG development may require the use of 

various water management alternatives, which include but are not limited to; deep injection, evaporation 

ponds, water treatment (such as freeze thaw evaporation, reverse osmosis, ion exchange, etc), direct 

discharge, and sub-surface drip irrigation. 

Project development will result in the use of new roads and roads previously constructed and currently 

used in the Project Area. New roads are expected to consist primarily of short access roads. Existing 

arterial roads will provide the main access to the Project Area. The project may also include the 

development of an overhead electrical system to provide commercial power to portions of the field, as 

well as lower voltage, buried power utilities to individual well pads. The overhead system is estimated to 

include approximately 36 miles of line. The construction disturbance width would be up to 25 feet. The 

overhead system would primarily follow existing road corridors and utility ROWs. The buried power 

utility to individual wells would be the responsibility of the Operators, and would be installed in the 

utility corridor adjacent to the well pad access road 

The Project Area includes approximately 1.1 million acres of mixed federal, state, and private lands. The 

BLM manages approximately 626,355 acres (59%), the State of Wyoming owns approximately 21,600 

acres (2%), and private landowners own approximately 421,360 acres (39%). The Project Area is 

generally located within Townships 14 through 24 North, Ranges 91 through 97 West, 6th Principal 

Meridian. The eastern boundary of the Project Area is about 25 air miles west of the city of Rawlins. 

Interstate 80 generally crosses through the center of the Project Area. 

B-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
MuddyG

R97W R96W R95W R94W R93W R92W R91W R90W R89

Bairoil 

Lamo

T26N 

WY WYOOMMIINNG G

T25N Project Area 

6 1 6 1
 

T24N 

31 36 31 36
 

1 6 1 6
 1 6
 1 6 6
 1 6 1

T23N 

31
 36 31
 36 31
 36 31
 

1 6 1 6
 

36 31
 36 31
 

1 6
 1 6
 1 6
 1 6
 

T22N 

31
 36 31
 36 31
 36 31
 36 31
 36 31
 

6
 1 6
 1 6
 1 6
 1 6
 1 6
 

T21N 

31 36 31 36 31 36 31 36 31 36 31
 

6 1 6
 Riner 

Creston 

T20N Wamsutter Latham

36 31
 36 31 36 31 36 31 36 31 36 31
 

1 6 1 6 1 6
 1 6
 1 6 1 6 1

Frewen 

T19N 

80
 

Table Rock 

Monell 

36 31
 36 31
 36 31
 36 31
 36 31 36 31 36 31
 

Bitter Creek 6 1 6 1 6
 1
 6 1 6
 1 6

T18N 

31
 36 31 36 31 36
 31
 36 31
 36 31
 

6 1 6
 1
 6 1 6 1
 

T17N 

36 31 36
 31 36 31
 

1 6 1 6 1 6
 

T16N 

36 31 36 31
 

1 6
 

Legend T15N 

Continental Divide - Creston 

Project Area 

Ownership T14N 

Bureau of Land Management 

State 

T13N Private 

0 1 5 Miles 0

SWEETWATER COUNTY

CARBON COUNTY

36 31 36
 

1 6 1 6
 

36 31 36 31
 

789
 

Baggs Dixon 

_

APPENDIX B—PLAN OF DEVELOPMENT 

ap 

W 

nt 

j y g j

Savery 

Map 1. Continental Divide-Creston Natural Gas Development Project 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-5 
 

 

APPENDIX B—PLAN OF DEVELOPMENT 

1.2 SUMMARY OF SURFACE DISTURBANCE
 

The Operators estimated projected surface disturbance using assumptions based on past experience and 

anticipated activities. A summary of the estimated project-related disturbance is shown in Table 1. 

Project development will result in disturbance to the federal, state, and private lands upon which the 

project wells will be drilled. Disturbance of the land will result from the construction and use of new 

roads, the construction of well pads, the installation of subsurface pipelines, and the construction or 

expansion of compressor facility sites or other associated facilities. Short-term disturbance refers to initial 

disturbance prior to interim reclamation of the reserve pits, unused portions of the location and roads, and 

reclamation of the pipeline route. Long-term disturbance refers to disturbance of the surface associated 

with the life of a well in addition to the running surface of access roads. 

For analysis purposes, the following assumptions were made: 

	 Average access road length will be 0.25 mile. 

	 Road disturbance width will be 55 feet, reclaimed to a running surface of 32 feet. Permanent road 

right-of-way is typically 50 feet. 

	 Initial disturbance associated with each well will average approximately 6.3 acres for single well pads, 

and 2.45 acres per well bore for multiple well pads. This acreage includes the associated road 

disturbance. The actual acreage per well bore on multi-well pads will vary based on the number of wells 

bores on the pad. 

	 Long-term disturbance associated with each well pad will be approximately 2.6 acres for single wells 

and 1.2 acres per well bore for multiple well pads. This acreage also includes the associated road 

disturbance. 

	 Average gas gathering pipeline length will be 0.25 mile. 

	 An average width of 25 feet will be physically impacted by utility construction, including gas, water 

pipelines, and power, which will be totally reclaimed after construction. Utility ROWs will be built 

adjacent to roads wherever possible and practicable. Operators may utilize a construction corridor of 

up to 75’ for utility installation dependent on the specifics of a given location. These corridors will be 

addressed in the ROW and/or APD filing procedure. 

	 The overhead electrical system would be approximately 36 miles long, and have a construction 

disturbance width of up to 25 feet. 

CBNG well pads have a smaller footprint than conventional wells, however, the acres of disturbance 

shown in Table 1 was calculated using conventional well pad dimensions due to the relatively small 

percentage of CBNG wells, and because the potential number of CBNG wells cannot be well defined at 

this stage of project development. CBNG well pads average about 3.8 acres during initial disturbance and 

1.25 acres during operations. 

Average access road length was estimated by taking into account that the proposed wells will be infill 

wells in an area that has an existing road system. Operators will be using the Transportation Plan to 

minimize construction of new roads; therefore, it is reasonable to assume that most new access roads will 

be constructed as laterals off existing roads. Consequently, the average new access road length was 

estimated at 0.25 mile. 

The Operators intend to construct and install pipelines adjacent to well access roads, however, it will be 

necessary to construct a pipeline route cross-country at some locations. Pipeline routes will be reclaimed 

after construction such that all surface disturbances resulting from pipeline construction will be short-term 

disturbance. Long-term disturbance associated with pipeline construction is expected to be very minimal 

after reclamation is complete. 

B-6 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

APPENDIX B—PLAN OF DEVELOPMENT 

The Operators will continue to limit long-term surface disturbance as much as possible through the 

implementation of a road network that minimizes the construction of new access roads and by reclaiming as 

much of the short term disturbance associated with roads and locations as is reasonable without limiting the 

requirements for ongoing and future production operations. 

Table B-1. Preliminary Estimate of Surface Area Disturbance1
 

Continental Divide – Creston Natural Gas Project
 

Facility Type 

Initial (Short Term) 

Disturbance Area2 

(acres) 

Area of Operations3 

(Long Term Disturbance Area) 

(acres) 

Well Pad Sites4 41889 17998 

Utilities 5 4897 449 

Water Management Facilities 6 270 270 

Compressor Facilities 7 144 144 

Total Disturbed Area 47200 18456 

Percentage of the Total Project Area8 4.29% 1.68% 

1) This table represents the total area estimated to be disturbed at the Continental Divide – 

Creston Development Project during its 15-year construction and 30 to 40 year operational life. 

2) The initial disturbance represents the area disturbed as a result of drilling and associated construction of well pad 

sites, roads, gas, condensate, and water collection pipelines, compressor stations, and power supply systems. 

3) Following drilling and associated construction, part of the initial disturbance will be reclaimed. The area not 

reclaimed will be used for operations. Once the gas resource is extracted, facilities will be removed and the area 

reclaimed entirely. 

4) An estimated 8,950 natural gas well bores will be established in the project area. 

Initial (Short Term) Disturbance Area: The initial well pad site disturbance for a vertical well will average 6.30 acres 

per well pad site which includes 0.9 of an acre for an access road. The initial disturbance for a directional well will 

average 2.45 acres per well bore completed including 0.45 acres for an access road (assumed 50% of the 

directional wells will need a new access road). 

Area of Operations (Long Term Disturbance Area): Following drilling and well installation, reclamation will reduce 

the vertical well pad sites to approximately 2.6 acres which includes 0.9 of an acre for a road. Following reclamation, 

the long-term disturbance for directional wells is estimated at 1.2 acres per well bore which includes 0.45 acres for 

an access road (assumed 50% of the directional wells will need a new road). 

5) Utilities include gas, condensate, and water collection pipelines, as well as buried powerline facilities. Generally, 

these utilities will parallel the access roads. An average width of 25 feet will be physically affected by the installation 

of utilities. Actual utility corridor construction width will vary by operator and site conditions. Assuming 0.25 miles of 

utility installation for a well pad site, an estimated 0.75 acres will be disturbed with utility installation for the well pad 

sites. Overhead power includes an estimated 36 miles of line, requiring a 25-foot wide construction corridor. 

6) Water Management Facilities – water will be handled using a combination of evaporation ponds, enhanced 

evaporation, water treatment, and injection wells. An estimated 30 injection wells affecting an estimated 5 acre per 

well and an estimated 20 produced water handling facilities are planned affecting an estimated 3.5 acres per facility. 

An estimated 1-acre will be disturbed per site for access roads. 

7) It is assumed that one central pipeline compression facility, estimated to affect approximately 10 acres, will be 

required for the project. It is assumed that 10 additional compressor stations will be required for the project. An 

estimated five acres will be physically affected at each compressor station site. Each compression site will require 

an access road assuming 32 feet width for 1⁄2 mile estimated disturbance of 2 acres per road per site. 

It is assumed that two or more central Gas Processing/Stabilization Plants will be needed within the Project Area. 

Each is estimated to affect approximately 30 acres. Each site will require a 1⁄2 mile access road estimated at 2 acres 

disturbance. 

8) This percentage is based on the 1.1 million acres within the EIS analysis area. 

9) Once buried utilities are constructed, the disturbed area will be reclaimed in its entirety. Overhead powerlines will 

require a 10-foot wide permanent corridor. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-7 
APPENDIX B—PLAN OF DEVELOPMENT 

2. Pre-Construction and Site Layout 

Activities associated with the development may include access roads, pipeline and well pad construction, 

drilling and well completion, and any other ancillary facilities needed to develop the particular phase. 

Prior to the start of any construction activities involving a federal action on BLM managed public land, 

Operators will submit a site specific APD/Notice of Staking (NOS)/ROW application to the BLM that 

will detail the development proposal. The application will include a map showing the specific location of 

the proposed activities and site-specific construction plans. A Plan of Development (POD) may be 

submitted for multiple wells within the same area for CBNG. 

The proposed development sites will be staked in the field by the applicant and inspected by the BLM to 

ensure consistency with the application. The appropriate NEPA documentation will be conducted to 

ensure that the proposal will comply with guidelines contained in the BLM’s Rawlins Resource 

Management Plan (RMP) 2008, specific requirements contained in the EIS/Record of Decision for the 

project, and current BLM policy regarding oil and gas development. 

Applications may be revised as necessary per discussions with BLM. The BLM may approve or deny 

site-specific proposals, and will attach any terms or conditions of approval to the permit. Upon receipt of 

BLM approval, the applicant can commence with proposed activities. 

B-8 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX B—PLAN OF DEVELOPMENT 

3. Construction Activities 

3.1 ROADS 

Since the project is an infill development in an existing well field, new road construction is not expected 

to be extensive. The primary access to the project area is Interstate 80. Wyoming State Highway 789, 

several Sweetwater and Carbon county roads, and other smaller local roads provide access within the 

project area. New road construction will primarily be short sections of road from the existing road 

network to the individual new well sites and support facilities. Some existing access roads may need to 

have some improvements to accommodate the increase in traffic and heavy construction equipment such 

as widening or gravelling. 

The exact locations of proposed roads are not known at this time. Specific locations for access roads will 

be included in APD and ROW applications, and will be evaluated by the BLM during the onsite 

inspections. Road construction will be in accordance with guidelines specified in the BLM Road 

Standards Manual, Section 9113, and with construction standards in its Surface Operating Standards for 

Oil and Gas Exploration and Development (BLM Gold Book, revised 2006). 

The construction width for access roads will typically be 55 feet. Standard cut and fill construction 

techniques will be used. Roads are usually crowned and ditched except where an operator or the BLM 

determine that the road can safely be constructed using less disruptive techniques. The permanent running 

width will not exceed 32 feet. Existing roads that require upgrading will meet standards appropriate to the 

anticipated traffic flow and all-weather requirements. Upgrading may include ditching, drainage, 

graveling, crowning, and capping the roadbed as necessary to provide a safe roadway. Maintenance 

practices may include dust abatement, road surface grading, and maintaining proper drainage. New roads 

may be graveled to accommodate year-round use, to allow the transport of heavy loads, and to minimize 

dust generation. Two-track roads may be constructed or utilized in some instances for access to smaller 

facilities. Access roads are planned to be reclaimed when no longer needed, unless the landowner or the 

BLM requests otherwise. 

3.2 WELL PADS 

The project will include the construction of 8,950 well bores from both single well pads and well pads 

with multiple directional well bores. Construction of a typical single well pad will require approximately 

6.3 acres which includes 0.9 acres for an access road. A typical multiple well pad will disturb 

approximately 2.45 acres per well bore, which includes 0.45 acres for an access road. Figures 2 through 6 

show examples of typical single and multiple well pads. Well pad layouts will vary between operators, 

but all will be constructed within the approved disturbance area. 

Operators will determine the location of a proposed well by the location of the subsurface reservoir, the 

topography of the area, and WOGCC spacing rules. Dimensions of a drill pad will depend on topography 

and specific well needs. Well pads will be constructed using the native sand/soil/rock materials present. 

Mineral materials will not be required. Topsoil and native vegetation will be removed and stockpiled for 

use in the reclamation process. Balancing cut and fill areas will level locations. Construction practices may 

include ripping to achieve a level pad. Cut-and-fill slopes will be designed to allow for retention of the 

topsoil during reclamation and subsequent re-establishment of vegetation. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-9 
APPENDIX B—PLAN OF DEVELOPMENT 

Figure B-1. Typical single well pad layout, example 1 

B-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX B—PLAN OF DEVELOPMENT 

Figure B-2. Typical single well pad layout, example 2 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-11 
APPENDIX B—PLAN OF DEVELOPMENT 

Figure B-3. Typical CBNG well site layout 

B-12 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX B—PLAN OF DEVELOPMENT 

Figure B-4. Typical multiple well pad layout, example 1 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-13 
APPENDIX B—PLAN OF DEVELOPMENT 

Figure B-5. Typical multiple well pad layout, example 2
 

B-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

APPENDIX B—PLAN OF DEVELOPMENT 

Typically a well pad will include a six to eight-foot wide cellar to allow access to casing heads, mouse 

and rat holes adjacent to the well bore to accommodate drilling operations, a flare or completion pit, and a 

reserve pit. A fenced reserve pit, approximately 10 to 12 feet deep, will be excavated within the pad to 

temporarily store drilling fluids and cuttings. The dimensions of the pit vary according to well depth and 

size and shape of location. In non-environmentally sensitive areas and when a fresh water-based drilling 

mud is used, the reserve pit may be unlined pending evaluation of the distance to surface water, depth to 

useable ground water, soil type and permeability, and anticipated types of fluids that will be contained in the 

pit. A reserve pit will be lined if so specified in the APD after the onsite evaluation. It will also be 

constructed in a way that minimizes the accumulation of surface runoff into the pit through the use of 

strategically placed subsoil/topsoil storage areas and/or the construction of berms and diversion ditches. 

Both the access road and well pad are typically constructed within three to seven days, depending on terrain 

and site limitations. Depending on availability of equipment and specific well construction requirements, 

from two to eight individuals may be present on location during construction activities at any given time. 

Personnel will access the location using an average of 3 to 5 light trucks each day during construction of the 

access and well pad. Construction equipment varies but can include bulldozers, motor graders, scrapers, 

backhoes, and trenchers. 

During operations, interim reclamation will reduce the size of the well pads to approximately 2.6 acres for 

a single well pad and to 1.2 acres per well bore for multiple well pads. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-15 
APPENDIX B—PLAN OF DEVELOPMENT 

4. Drilling and Completions 

4.1 DRILLING 

Drilling operations will be conducted in compliance with all Federal Oil and Gas Onshore Orders, all 

WOGCC rules and regulations, and all applicable local rules and regulations. The Operators anticipate 

that the drilling rig count within the Project Area will range from about 34 to 70 rigs at any particular time 

in order to achieve development objectives. 

Following construction of the access road and well pad, a drilling rig will be transported to the well site 

and erected on the well pad. Wells will be drilled utilizing a conventional, mechanically powered mobile 

drilling rig. The rig will be erected at the drill site after the conductor pipe has been set. Drilling 

operations will consist of drilling surface hole, running and cementing surface casing, drilling production 

hole, and running and cementing production casing. The rig may then be dismantled and demobilized 

from the location. 

Fresh water will used for drilling the first 5,000 to 7,000 feet of each gas well (500 to 1000 feet for each 

CBNG well), and water-based muds being used for the remainder of the drilling operation. Water will 

come from existing and new water supply wells within the project area, as well as from produced water 

sources which will conserve fresh-water aquifers. Operators will obtain all necessary permits for any 

water well drilling. Water from reserve pits may be transferred and used for drilling. 

Drilling fluids will primarily consist of a fresh water/gel mixture with water being the main constituent. 

Reserve pits will be constructed so as minimize the potential to leak, break, or allow discharge and in 

accordance with APD Conditions of Approval (COAs). The reserve pit will be fenced on three sides 

during drilling operations and on the fourth side when the rig moves off the location. Fences will be 

constructed according to BLM requirements on Federal surface and/or Federal minerals. 

During drilling operations, a blow out preventor (BOP) will be installed on the surface casing to provide 

protection against uncontrolled surface blowouts should reservoir pressures exceed the hydrostatic 

pressure of the well bore fluid. In addition, a flow control manifold consisting of manual and 

hydraulically operated valves will be installed below the rig floor. 

Prior to setting production casing, open hole logs may be run to evaluate production potential. If deemed 

economically justified, steel production casing will be run and cemented in place in accordance with the 

well design and as specified in the APD and COAs. Evaluation logs may be run subsequent to setting and 

cementing production casing in some cases. 

The types of casing used and the depths to which they are set will depend upon the physical 

characteristics of the formations that are drilled and the pressure requirements anticipated during 

completion and production operations. All casing will be new or inspected. 

Operators propose to drill year-round within the CD-C project area, subject to environmental 

considerations. Well development will include single wells and directional wells. Drilling each gas well 

will take about 10 to 20 days, with additional time likely for directional wells, and wells deeper than 

10,000 feet. CBNG wells typically take 6 to 14 days to drill. Drilling operations require approximately 8 

to 10 personnel and six vehicles on location at any given time each day during normal operations. An 

additional 10 to 15 personnel and six vehicles will be required on location during the running and 

cementing of production casing. Approximately 20,000 to 30,000 barrels of water are needed to perform 

drilling operations for both gas and CBNG wells. Operators propose to utilize produced water as 

appropriate as a conservation tool. 

B-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX B—PLAN OF DEVELOPMENT 

4.2 MATERIALS MANAGEMENT
 

Potentially hazardous substances used in the development or operation of wells will be kept in limited 

quantities on well sites and at the production facilities as needed for operations. Materials will not be 

stockpiled at well locations. The transport, use, storage and handling of hazardous materials will follow 

the procedures specified by the Occupational Safety and Health Act and by the Department of 

Transportation (DOT) under 49 CFR, Parts 171–180. DOT regulations pertain to the packing, container 

handling, labeling, vehicle placards, and other safety aspects. 

None of the chemicals that will be used meet the criteria for being an acutely hazardous 

material/substance or meet the quantities criteria per BLM Instruction Memorandum No. 93-344. 

Chemicals subject to reporting under Title III of the Superfund Amendments and Reauthorization Act in 

quantities of 10,000 pounds or more will not be used, produced, stored, transported, or disposed of 

annually during the drilling, completion, or operation of any well in the Project Area. In addition, no 

extremely hazardous substance, as defined in 40 CFR 355, in threshold planning quantities, will be used, 

produced, stored, transported, or disposed of while producing any well. 

4.3 SOLID AND HAZARDOUS WASTE 

Most wastes that will be generated at project locations are exempt from regulation by the Resource 

Conservation and Recovery Act under the oil and gas exploration and production exemption and are 

considered to be solid wastes. These wastes include those wastes generated at the wellhead and through 

the production stream and gas plant. Exempt wastes include produced water, drilling mud, well 

completion/workover fluids, and soils affected by these exempt wastes. 

Spills and releases can result in soils that are contaminated by produced water, petroleum products, or 

chemicals. The Operators will develop and maintain Spill Prevention Control and Countermeasure Plans 

for each well in the Project Area. 

4.4 COMPLETIONS AND TESTING 

A typical cased well bore in the Project Area consists of conductor pipe, surface casing, and production 

casing. The surface and production casing/cementing programs will be designed to isolate and protect 

shallower formations and aquifers from the production stream and to minimize the potential for migration 

of fluids and pressure communication between formations. 

A cementing plan is submitted with the drilling plan as part of the APD. This plan is reviewed by 

the BLM and/or the Wyoming Oil and Gas Conservation Commission. The BLM can request 

additional information or apply COAs relating to the cementing plan if necessary. 

Once production casing has been cemented in place, the drilling rig may be released and completion 

operations will commence utilizing a well servicing rig or coiled tubing unit. In some cases completions 

can be performed by the drilling rig. Initial completion operations may also be conducted “rigless,” 

utilizing cased hole wireline equipment rather than a well servicing unit or coiled tubing unit, until such 

time that production tubing is installed in the well or other operational requirements dictate the use of a 

well servicing rig. In general, the completion of the well will consist of perforating the production casing, 

productivity and/or formation pressure testing if deemed necessary, stimulation of the formation(s) 

utilizing hydraulic fracturing technology, flow back of fracturing fluids, flow testing to determine post 

fracture productivity, and installation of production equipment to facilitate hydrocarbon sales. 

Hydrocarbons and water production rates are typically quantified and flared during testing operations, 

which are conducted on an as-needed basis. Flareless or reduced flaring technology may be utilized for 

well completions if appropriate. Hydraulic fracture stimulation is required on the majority of wells in the 

Project Area in order to enhance productivity. Numerous combinations of fluids and proppants have been 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-17 
APPENDIX B—PLAN OF DEVELOPMENT 

used historically in the Project Area in the effort to optimize stimulation results. Currently, the most 

common stimulation technique utilizes gelled fresh water (with CO2 and/or N2 frequently added for 

reservoir protection and enhanced flow back) and fracture proppants to provide the bridging and increased 

permeability necessary for productivity improvement. Sand, resin-coated sand, ceramics, or bauxite can 

be used as proppants in the stimulation process, depending on the design criteria of individual treatments. 

Gels and other chemical additives are utilized to provide the fluid viscosity necessary to ensure successful 

stimulation. The fracturing fluid is pumped down the well bore through the perforations in the casing, and 

into the formation. Sufficient rate and pressure are reached to induce a fracture in the target formation. 

The proppant carried in the fluid serves as a bridge to keep the created fracture open and to provide a flow 

path that allows reservoir fluids to move more readily into the well bore. Water used for stimulation 

purposes generally comes from water supply wells. Stimulation fluids recovered during flow back and 

subsequent production operations are temporarily contained in the completion, flare, or reserve pit. 

Post stimulation flow tests allow for recovery of stimulation fluids and evaluation of well productivity. 

Duration of the tests will vary depending on individual well performance but typically are conducted only 

long enough for fluid rates to drop to a level that permanent production equipment can safely process. Gas 

is commonly flared during the flow back process and is measured using choke nipple calculations or 

through a temporary flow test separator and metering facility. Flaring takes place at the end of a 

horizontal flow line placed at a temporary pit designed for that specific purpose or at a vertical flare stack. 

Flaring occurs at a distance from the wellhead that ensures equipment and structure protection and 

personnel safety. Following the initial flow period, the well may be shut in until facilities are in place to 

allow the well to be placed on sales. In some cases, production facilities will be installed prior to 

completion in order to provide the capability of turning the well to sales immediately following testing. 

Alternatively, if flareless or reduced flaring completions technology is utilized, production facilities and 

flowlines will be installed prior to well completion. Special separation equipment is then needed to 

process the flowback to remove sand and fluids thereby allowing the gas to be turned to pipeline for sales 

rather than sent to flare. Fluids, primarily water, recovered during flow back operations are contained in 

the completion pit until they are disposed of at evaporation ponds, disposal wells, or evaporated on 

location. 

Current technology allows for CBNG wells to be stimulated with high-pressure water and frac sands. 

After the well is completed, the well is either vented temporarily to atmosphere or directly tied into the 

gathering system. The water and CBNG will be separated downhole. 

Completion and testing operations typically require approximately 10 to 20 (up to 30) days to perform, 2 

to 30 personnel, and 1 to 20 vehicles on location. Approximately 4,000 to 12,000 barrels of water per well 

will be needed for completion and testing operations. 

In the event a well proves to be uneconomic, the Operator will plug and abandon the well in accordance 

with federal and state regulations. 

4.5 INTERIM RECLAMATION 

On producing wells, the reserve pit will be reclaimed per the requirements specified in the approved APD. 

Reserve pits may be re-used for multiple wells being drilled from a single pad. Plastic liners, if used, will 

be buried onsite. The reserve pit, that portion of the location and access road not needed for production 

operations, and pipeline corridors will be reclaimed according to the requirements specified in the 

approved APD and COAs. Locations and roads will be reclaimed and reseeded back to the minimum size 

required as soon as possible after the well is put into production. CBNG well pads will also be reclaimed 

to a smaller size after the initial drilling phase, but roads typically stay at the construction dimension due 

to their initial minimum construction footprint. Each Operator may have a slightly different restored 

configuration based on original disturbance and the number of wells drilled on location. Figure 7 shows 

an example of a well pad layout after interim reclamation. 

B-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX B—PLAN OF DEVELOPMENT 

Figure B-6. Well pad after interim reclamation 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-19 
 

APPENDIX B—PLAN OF DEVELOPMENT 

5. Production and Maintenance 

5.1 WELL PRODUCTION FACILITIES 

Well production facilities will be installed as shown on the approved APD, with secondary containment 

structures built to conform to BLM, state, and federal requirements. Facilities on the well pad will 

typically include wellhead valves and piping, separation, dehydration, metering equipment, oil and water 

production tanks, a methanol storage tank and pump, and telemetry equipment. Production equipment 

will be fueled by natural gas or electricity. Telemetry equipment is currently used or planned for use by 

most Operators to improve well evaluation, operational efficiency, and to minimize well visits. 

Production pits will not be used. Well site compression may be utilized on an as-needed basis. 

CBNG wellhead equipment may be run on diesel generators until an adequate flow of gas is present to 

run a gas-fired engine. Electricity may be provided to some CBNG sites in the future. 

Artificial lift is equipment that is installed when production volumes drop to a level that prevents efficient 

removal of liquids from the well bore using reservoir energy alone. Artificial lift is presently limited to the 

use of plunger lift equipment , which is a passive hydraulic means of removing liquids from the well bore 

and does not require any increase in the disturbed surface area. Gas lift, downhole pumps, or other 

technology may also be employed. 

All constructed or installed permanent structures (on site six months or longer) will be painted a flat, nonreflective earth-tone color as specified by the BLM. All new project facilities requiring painting will be 

painted within six months of installation. 

5.2 PIPELINES 

The Operators will continue to utilize the existing natural gas transmission lines that serve the Project Area. 

Operators are not responsible for the construction or operation of gas transmission lines, and new 

transmission lines are not included as a component of the Operators proposed project. 

Gathering lines will be installed below the surface to transport the produced gas from the new wells to the 

gas gathering pipeline system. The gas production lines will be located adjacent and parallel to well access 

roads where possible to minimize surface disturbance. The exact location of a gathering line will be 

determined at the time of the onsite with the appropriate surface management agency. The new pipelines 

are expected to cross federal, state, and private surfaces in a route developed to minimize both resource 

conflicts and development costs within the Project Area. Approximately 45 miles of high-pressure gas 

lines may be installed to service multiple CBNG wells in the northwest portion of the project area. This 

pipeline will generally run in a north-south alignment from Wamsutter north to the Hay Reservoir area. 

Pipeline construction consists of trenching, pipe stringing, bending, welding, coating, lowering pipeline 

sections into the trench, and backfilling. Construction operations will be confined to the ROW corridor 

approved in the ROW application which is variable between operators. In general, construction widths 

will be 50 to 75 feet when not adjacent to a road and 25 to 50 feet when adjacent to an existing or new 

road. Pipes installed adjacent to road ROWs are constructed outside of the borrow ditch to minimize 

safety concerns. The pipeline trench will be mechanically excavated with a backhoe or trencher to a 

minimum depth of 48 inches. The trench will be approximately 18 to 20 inches wide. Newly constructed 

pipelines will be hydrostatically tested to ensure structural integrity. As an example of water 

requirements, approximately 2,700 gallons of water will be required to test one mile of four-inch pipeline. 

Hydrostatic test water will be disposed of as approved by the BLM and/or the State. Pipeline corridors 

will be reclaimed as specified in the COA authorization. Pipelines installation will result in short term 

disturbance until reclamation is considered complete. 

B-20 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

APPENDIX B—PLAN OF DEVELOPMENT 

5.3 COMPRESSION, GAS TREATMENT, AND ANCILLARY FACILITIES
 

The existing compression infrastructure, however, will be unable to provide sufficient capacity to compress 

the additional gas volumes anticipated from the proposed wells. Additional compression will also be 

required if the Operators conclude that a reduction in gas gathering system pressure is needed at some point 

during the life of the project. Additional compression will be added to existing compression infrastructure 

where appropriate. Additionally, the Operators estimate that one large central pipeline compression facility, 

affecting approximately 10 acres, may be required for the project. Peak production is expected to occur in 

the 11th year after project approval. As many as ten additional compressor sites at 5 acres per site could be 

required to accommodate the maximum anticipated compression growth. Compression requirements and 

associated horsepower estimates will be developed in association with the air quality analysis. 

Well site compression is utilized infrequently in the Project Area; however, individual well site compression 

could be needed on a limited basis. Well site compression will be installed on the existing well pad resulting 

in no additional disturbance. Well site compression typically uses 125 to 200 hp two-stage compressors. Gas 

fueled compression equivalent to 2500 HP per pilot will be required during the pilot phase for some of the 

CBNG development. Pilot testing will last for three years. Eight pilots can be expected within the EIS 

boundary area. 

It is anticipated that two or more central gas processing/stabilization facilities will be needed within the 

Project Area. It is estimated that each of these facilities could affect 30 acres. 

The Operators will utilize the existing facility infrastructure within the Project Area to the extent possible, 

including power lines and gas gathering and transmission pipelines. 

5.4 PRODUCED WATER DISPOSAL 

Produced water from conventional production may be stored in tanks at the well site prior to transport by 

water hauling trucks or transported in flowlines to collection facilities for disposal. Produced water will be 

disposed of via subsurface injection, surface evaporative pits, or will be used for potential beneficial use (i.e. 

drilling operations). Conventional wells average 18 bbls/day or produced water. Produced water, condensate 

and gas will be separated at the well site or at central facilities. The proposed development includes a 

percentage of CBNG wells. CBNG wells can produce from 500 to 1000 bbls/day of produced water. 

Produced water and gas will be separated at the well site. Water may be stored on-site in a lined pit or 

storage tank, or water collection lines may be installed to transport water to a water treatment facility, 

evaporation ponds, injection wells, subsurface drip areas and/or approved discharge points. Water gathering 

lines of various sizes will be installed adjacent to roads/gas pipelines. Any surface discharge of produced 

water from CBNG wells is regulated under a National Pollutant Discharge Elimination System (NPDES) 

permit issued by the Wyoming Department of Environmental Quality (WDEQ). Produced water quality will 

be monitored in accordance with State and Federal regulations. 

5.5 MAINTENANCE 

New wells will typically be visited daily but possibly less frequently after well performance has stabilized 

and telemetry equipment is installed. 

Road travel will be restricted to the width of the running surface of the road. Maintenance on project roads 

during drilling and construction will be the responsibility of the Operators and will be consistent with the 

Transportation Plan, annual road plan, well-specific project plan, and BLM specifications. During the 

duration of the proposed project, the Operators will monitor the project roads and perform appropriate 

repairs. Repairs may be necessary to correct excessive soil movement, rutting, braiding around problem 

areas, and/or damage to cattle guards or gates. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-21 
APPENDIX B—PLAN OF DEVELOPMENT 

5.6 WORKOVERS 

Periodically, a workover on a well may be required. A well servicing rig is generally utilized during 

workover operations to perform various tasks such as well bore or surface equipment repairs, reservoir 

evaluation, or stimulation treatments to restore or enhance well performance. Workover operations are 

typically performed during daylight hours and are of short duration; however, depending on the scope of 

the work to be performed, workover operations can sometimes take from several days to several weeks to 

be completed. Unless fracture stimulation is necessary, workover operations typically require from five to 

10 workers on location at any given time. During fracture treatments, an additional 10 to 20 individuals 

could be present on location. Additional surface disturbance is rarely necessary to conduct workover 

operations. Approval from the BLM Authorized Officer (AO) will be requested should the need for new 

surface disturbance arise. 

5.7 GEOPHYSICAL OPERATIONS 

Seismic surveys have been conducted on some portions of the CD-C Project Area in the past. Additional 

seismic surveys are currently being planned and are needed to further define the subsurface to facilitate 

the extraction of leased oil and gas resources. Proposed seismic surveys are currently under analysis in a 

separate BLM NEPA review, and are not included in this proposal. 

B-22 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX B—PLAN OF DEVELOPMENT 

6. Reclamation and Abandonment 

Abandonment of the well and its facilities will be performed in compliance with applicable federal and 

state regulations as well as the COAs to the APDs. Seed mixtures applied during rehabilitation operations 

will comply with the specifications of the appropriate surface management agency. The Operators will cut 

off the casing at the base of the cellar or three feet below the final graded ground level, whichever is 

deeper, and cap the casing with a minimum of 0.25 inch thick metal plate. The cap will be welded in 

place with the well name and location engraved on the top. The cap will be constructed with a weep hole. 

All surface equipment will be removed from the site. The surface will be recontoured to its original 

appearance, to the extent possible. Topsoil will be distributed above the former location to blend the site 

in with its natural surroundings. All surface disturbance will then be planted with a seed mixture as 

specified by the appropriate surface management agency. Reclaimed sites will be monitored to ensure 

erosion is prevented and the desired plant species are being re-established. Monitoring will continue until 

the reclamation is deemed successful, which will be defined in the project reclamation plan. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-23 
APPENDIX B—PLAN OF DEVELOPMENT 

7. Operator-Committed Practices 

The Operators will adhere to all lease and APD conditions in addition to all federal and state laws, 

regulations, and policies implemented through statute and/or resource management planning decisions 

implemented through NEPA. According to BLM IM No. 2004-194, best management practices to be 

considered in nearly all circumstances include the following: 

	 Interim reclamation of well locations and access roads soon after the well is put into production; 

	 Painting of all new facilities a color which best allows the facility to blend with the background, 

typically a vegetated background; 

	 Design and construction of all new roads to a safe and appropriate standard, “no higher than 

necessary” to accommodate their intended use; and 

	 Final reclamation recontouring of all disturbed areas, including access roads, to the original 

contour or a contour that blends with the surrounding topography.
 

The Operators commit to performing these environmental protection measures during the implementation 

of their proposed project. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 B-24 
Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-i 

APPENDIX C: BEST MANAGEMENT PRACTICES AND CONDITIONS 

OF APPROVAL 

Table of Contents

Best Management Practices ...................................................................................................... 1

APD Conditions of Approval ...................................................................................................... 1

Conditions of Approval .............................................................................................................. 3

GENERAL ............................................................................................................................................. 4

OPERATIONS ....................................................................................................................................... 6

CONSTRUCTION ................................................................................................................................. 9

ROADS ................................................................................................................................................ 11

PITS ...................................................................................................................................................... 13

FLUIDS ................................................................................................................................................ 14

RECLAMATION ................................................................................................................................. 14

DRILLING ........................................................................................................................................... 17

BOPE .................................................................................................................................................... 17

SITE SPECIFIC ................................................................................................................................... 21

Right-of-Way Terms and Conditions ....................................................................................... 21

 
 

 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

BEST MANAGEMENT PRACTICES 

BLM describes best management practices (BMPs) as “state-of-the-art mitigation measures applied to oil 

and natural gas drilling and production to help ensure that energy development is conducted in an 

environmentally responsible manner.” The aim of BMPs is to protect wildlife, air quality, landscapes, and 

other natural resources as energy resources are developed. BMPs tend to be general principles for 

resource protection and are not in themselves regulatory in nature. 

BLM’s policy is that all “Field Offices consider BMPs in National Environmental Policy Act (NEPA) 

documents to mitigate anticipated impacts to surface and subsurface resources, and also to encourage 

Operators to actively consider BMPs during the application process.” (Instruction Memorandum No. 

2004-194; June 22, 2004) Substantial information on BMPs can be found on BLM’s national website at: 

http://www.blm.gov/wo/st/en/prog/energy/oil_and_gas/best_management_practices.html. 

Another important source of information on BMPs is the publication Surface Operating Standards and 

Guidelines for Oil and Gas Exploration and Development (commonly referred to as The Gold Book), 

which was developed to assist Operators on the requirements for obtaining permit approval and 

conducting environmentally responsible oil and gas operations on Federal lands. It is available online at: 

http://www.blm.gov/wo/st/en/prog/energy/oil_and_gas/best_management_practices/gold_book.html 

BMPs that may have particular application to the Rawlins Field Office can be found in the following parts 

of the Rawlins Resource Management Plan (RMP) (BLM 2008): 

 Appendix 1—Wyoming Bureau of Land Management Mitigation Guidelines for Surface Disturbing 

and Disruptive Activities 

 Appendix 13—Reducing Nonpoint Source Pollution with Best Management Practices 

 Appendix 15—Best Management Practices for Reducing Surface Disturbance and Disruptive 

Activities 

 Appendix 16—Mountain Plover Management Guidelines: Occupied Habitat Protection Measures 

 Appendix 24—Mitigation Guidelines for Special Status Plants 

These appendices and the entire Rawlins RMP Record of Decision can be found at: 

http://www.blm.gov/wy/st/en/programs/Planning/rmps/rawlins/rod_armp.html 

BMPs are often expressed in natural gas leaseholders’ plans of development, in reclamation plans, or, 

attached to approved Applications for Permit to Drill, as Conditions of Approval, which are described 

below. 

APD CONDITIONS OF APPROVAL 

In the process of acquiring permission to drill to a federal oil and gas lease, leaseholders submit an 

Application for Permit to Drill (APD) to the BLM Field Office that manages the public lands where their 

lease is located. Included with the APD are: 

	 a drilling plan that contains a description of the leaseholder’s drilling program, geologic 

data, expected hazards and proposed mitigation measures to address such hazards; 

	 a surface use plan of operations that describes the locations of the drillpad and the access 

road, details of pad construction, and methods for containment and disposal of waste 

material; and 

	 a reclamation plan, which includes a weed management plan. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-1 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

When the BLM has completed the necessary environmental and technical review of the proposal 

contained in the APD, the BLM may approve the APD (or right-of-way application) as submitted or, 

more typically, approve the APD subject to Conditions of Approval (COAs) (or terms and conditions in 

the case of a right-of-way grant). 

COAs are attached to an approved APD to ensure environmental protection, safety, and/or conservation 

of the mineral resource. They arise from a variety of controlling authorities such as the Federal Land 

Policy and Management Act (FLPMA), the National Environmental Policy Act (NEPA), the Endangered 

Species Act (ESA) and the National Historic Preservation Act (NHPA). The COAs attached to an APD 

can be general in nature or site-specific, and thus will vary from one BLM Field Office to another. 

Typically, a Field Office develops COAs over a number of years of active management of oil and gas 

development. Often the Field Office RMP provides either a listing of potential COAs or the BMPs that 

might guide development of site-specific COAs in that area. They can address topics as wide-ranging as 

protection of wildlife habitat or archeological and paleontological sites, noise reduction, wildfire 

suppression, or management of invasive species. A BLM study of a number of Field Offices that manage 

oil and gas development identified 175 different types of COAs that are used to mitigate surfacedisturbing activities. (BLM 2006c) Following is a master list of COAs that are used in the Rawlins Field 

Office when considering APDs. The list is adapted as needed for site-specific use. Many of the items 

listed will not be used on a specific APD if not warranted. If, on the other hand, conditions call for 

requirements that are not on the list, BLM specialists can add new COAs. The list is presented in the 

standard format used for attachment to an approved APD. 

C-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

GOVERNMENT ADDRESS
 

ACTIONS REQUIRING BLM NOTIFICATION
 

AUTHORIZED OFFICER REPRESENTATIVE CONTACTS
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

CONDITIONS OF APPROVAL 

APPLICATION FOR PERMIT TO DRILL 

Operator XYZ Natural Resources, Well Name/No. Magic Mountain Federal 123 

LLP 

Lease No. WYW-999999 Legal Description NE1⁄4, NE1⁄4, Sec. 37, T 00 N, R 99 W 

USDI, BUREAU OF LAND FIELD OFFICE Rawlins 

MANAGEMENT 

ADDRESS 1300 North Third Street 

P.O. Box 2407 

Rawlins, WY 82301 

OFFICE PHONE (307) 328-4200 

OFFICE HOURS 7:45 a.m. to 4:30 p.m. (Monday - Friday) 

For construction, reclamation, and spud notices, submit via the www.wy.blm.gov/rfo/og.htm internet at: 

For running casing, cementing, BOPE tests, drill stem tests or other 

notices, call the following number 24 hours in advance of (307) 328-4276 (voice mail) 

commencing operations and leave voice message with call back 

number.
 

If you seek immediate approval or emergency assistance on any action that is related to the APD Surface Use 

Plan, contact the Natural Resource Specialist listed below. 

If you seek immediate approval or emergency assistance on any action that is related to the APD Drilling Plan 

or other down hole issues, you should contact the Petroleum Engineer listed below. 

Natural Resource Specialist 

Petroleum Engineer (Primary Contact) 

In the event the Petroleum Engineer named above is unavailable, please contact one of the following:
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-3 
A COMPLETE COPY OF THE APPLICATION FOR PERMIT TO DRILL, THE CONDITIONS OF 

APPROVAL, and APPLICABLE MAPS MUST BE FURNISHED TO YOUR FIELD REPRESENTATIVE 

AND BE AVAILABLE ON SITE DURING CONSTRUCTION AND DRILLING ACTIVITIES.
 

 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

Petroleum Engineer (Second Contact) 

Petroleum Engineer (Third Contact) 

Work 

Phone 

(307) 332-9999

 Home 

Phone 

(307) 332-9999 

Rev. 2007-05-01 

GENERAL 

1.	 Approval of this Application for Permit to Drill (APD) does not warrant that any party holds 

equitable or legal title. 

2.	 All lease exploration, development, construction, production, operations, and reclamation activity 

shall be conducted in a manner which conforms to all applicable federal, state, and local laws and 

regulations. 

3.	 All lease operations are subject to the terms of the lease and its stipulations, the regulations of 43 CFR 

Part 3 100, Onshore Oil and Gas Orders, Notices to Lessees (NTL's), the approved APD, and any 

written instructions or Orders of the Bureau of Land Management (BLM) Authorized Officer (AO). 

4.	 The approval of this APD does not grant authority to use off-lease federal lands. Facilities approved 

by this APD and/or Sundry Notices that are no longer included within the lease, due to a change in 

the lease or unit boundary, will be authorized with a right-of-way. Similarly, should unit or lease 

boundaries change during the life of the project, the Operator will be responsible for acquiring 

necessary rights-of-way for affected facilities. Failure to do so may cause the operation to be shut-in. 

5.	 This permit is valid for a period of two years from the date of APD approval or until lease expiration 

or termination, whichever is sooner. APD extensions may be requested and granted for up to two 

additional years, but not to exceed a total sum of four years from the initial APD approval date. 

Should a permit extension be requested, it must be submitted prior to the permit expiration date via a 

Sundry Notice (Form 3160-5) to the AO for approval. If the permit terminates, any surface 

disturbance created under the application shall be reclaimed in accordance with the approved 

reclamation plan found herein. 

6.	 The Operator shall submit a Sundry Notice (Form 3160-5) to the AO for approval prior to beginning 

any new surface-disturbing activities or operations that are not specifically addressed and approved 

by this APD. 

7.	 The Operator may submit to the AO's Representative written requests (including documentation, 

supporting analysis and an acceptable plan for mitigation of anticipated impacts) for exception, 

waiver, or modification to this approved APD, associated Conditions of Approval (COA), or other 

requirements. Such written approval shall be obtained prior to commencement of operations that 

cause any deviation from the approved APD and associated limitations. Emergency approval may be 

obtained orally, but such approval does not waive the written reporting requirement. 

C-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

8.	 At least 48 hours prior to beginning any APD-related construction (e.g. access road, well pad, 

pipeline) and/or reclamation activities (e.g. dirt-work, seeding) the Operator shall notify the BLM via 

internet notice. 

9.	 All construction of the well pad, flare pit, reserve pit, roads, flow lines, production facilities, and all 

associated infrastructure on federal lands shall be monitored onsite by a licensed professional 

engineer OR designated qualified inspector (to be named at the time of construction notification) who 

will serve as the Operator's Compliance Coordinator to ensure construction meets the BLM-approved 

plans. 

10. Within 24 hours of spudding the well, the spud date shall be submitted to the BLM via internet 

notice. A follow-up report on Form 3 160-5 confirming the date and time of the actual spud shall be 

submitted to this office within 5 working days from date of spud. 

11. At least 24 hours in advance of all BOP tests, running and cementing all casing strings (other than 

conductor casing), pluggings, DST's and/or other formation tests, and drilling over lease expiration 

dates, notification shall be submitted to the BLM via internet notice. 

12. Prior to construction, the Operator shall submit a production facility layout for approval (Onshore 

Order 1, Section 111. D.4.d. and D.4.i., or Section VIII. A.) that includes permitted location 

boundaries, production facility placement, access road inlet, and cut/fill slopes. 

13. A site facility diagram (Onshore Order 3, Section 111. I. and 43 CFR 3 162.7-5(d)) for the purpose of 

a site security plan (Onshore Order 3, Section 111. H. and 43 CFR 3 162.7-5(c)) shall be filed no later 

than 60 calendar days following first production. 

14. Use of any tank heater/burners in production storage tanks must be approved by the AO prior to 

installation and/or use. Failure to obtain approval for installation/use of tank heater/burners in any 

production storage tanks may result in a Written Order (WO), Incidence of Non-compliance (INC), 

assessments and/or potentially a Shut-In Order. 

15. No below or partially below ground fluid storage/containment tanks or vessels are to be used without 

prior approval of the AO. Below or partially below ground fluid storage/containment tanks or vessels 

shall require systems for the prevention, containment, detection, and monitoring of any below ground 

leakage (e.g. secondary containment and leak detection/monitoring systems, etc.). A production 

facility layout depicting the proposed vessel construction and installation/location must be submitted 

for prior approval via APD or Sundry. As applicable, all subsurface vessels must comply with the 

Wyoming Storage Tank Act of 2007 (W.S. 35-1 1-14-29) and/or the Wyoming DEQ Underground 

Injection Control (UIC) Program. 

16. No pipelines or flow-lines or related rights-of-way are approved with the APD. Well pipelines or 

flow-lines and related rights-of-way, including plans of development, must be submitted for approval 

via Sundry Notice or Right-of-Way Application (SF-299) as applicable, prior to construction. 

17. The BLM AO may request and schedule a meeting with the Operator or Operators representative to 

discuss the APD and terms and COAs. Such meeting would be held in the BLM offices, within 30 

days of the APD approval. 

18. The BLM AO may request to schedule a meeting with the Operator or Operators representative (dirt 

contractor, construction contractor, surveyors, etc.) to discuss construction and related requirements. 

Such meetings would be held in the BLM office and in the field within 60-90 days prior to surface 

disturbance and construction. The BLM AO may require surveys and re-stacking of all project 

construction and disturbance prior to field inspection. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-5 
APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

OPERATIONS 

1.	 Upon request, Operator must be prepared to provide copies of applications for, and approved copies 

of, federal, state, and local operating permits. 

2.	 All survey monuments found in the area of operations shall be protected. Survey monuments include, 

but are not limited to: General Land Office and BLM Cadastral Survey Comers, reference corners, 

witness points, U.S. Coastal and Geodetic benchmarks and triangulation stations, military control 

monuments, and recognizable civil (both public and private) survey monuments. In the event of 

obliteration or disturbance of any of the above, the Operator shall immediately report the incident, in 

writing, to the AO and the respective installing authority if known. Where General Land Office or 

BLM Right-of-way monuments or references are obliterated during operations, the Operator shall 

secure the services of a registered land surveyor or a BLM cadastral surveyor to restore the disturbed 

monuments and references using surveying procedures found in the "Manual of Surveying 

Instructions for the Survey of the Public Lands in the United States," latest edition. The Operator shall 

record such survey in the appropriate county and send a copy to the AO. If the Bureau cadastral 

surveyors or other federal surveyors are used to restore the disturbed survey monument, the Operator 

shall be responsible for the survey cost. 

3.	 If any cultural values (sites, artifacts, human remains) are observed during operation of this 

lease/permit/right-of-way, they will be left intact and the AO notified. The AO will conduct an 

evaluation of the cultural values to establish appropriate mitigation, salvage or treatment. The 

Operator is responsible for informing all persons in the area who are associated with this project that 

they will be subject to prosecution for knowingly disturbing historic or archaeological sites, or for 

collecting artifacts. If historic or archaeological materials are uncovered during construction, the 

Operator is to immediately stop work that might further disturb such materials, and contact the AO. 

Within seven (7) days after the Operator contacted the BLM, the AO will inform the Operator as to: 

whether the materials appear eligible for the National Register of Historic Places; the mitigation 

measures the Operator will likely have to undertake before the site can be used (assuming in situ 

preservation is not necessary); and, a time-frame for the AO to complete an expedited review under 

36 CFR 800.11 to confirm, through the State Historic Preservation Officer, that the findings of the 

AO are correct and that mitigation is appropriate. The AO will provide technical and procedural 

guidelines for the conduct of mitigation. Upon verification from the AO that the required mitigation 

has been completed, the Operator will then be allowed to resume construction. 

4.	 The Operator will be responsible for the cost of any mitigation required by the AO. The AO will 

provide technical and procedural guidelines for the conduct of mitigation. Upon verification from the 

AO that the required mitigation has been completed, the Operator will be allowed to resume 

operations. 

5.	 If paleontological resources, either large or conspicuous, and/or of a significant scientific value are 

discovered during construction, the find will be reported to the AO immediately. Construction will be 

suspended within 250 feet of said find. An evaluation of the paleontological discovery will be made 

by a BLM-approved professional paleontologist within five (5) working days, weather permitting, to 

determine the appropriate action(s) to prevent the potential loss of any significant paleontological 

values. Operations within 250 feet of such a discovery will not be resumed until written authorization 

to proceed is issued by the AO. The Operator will bear the cost of any required paleontological 

appraisals, surface collection of fossils, or salvage of any large conspicuous fossils of significant 

scientific interest discovered during the operation. 

6.	 The Operator will be responsible for informing all persons associated with this project that they will 

be subject to prosecution for damaging, altering, excavating or removing any archaeological, 

historical, or vertebrate fossil objects or site. If archaeological, historical, or vertebrate fossil materials 

are discovered, the Operator shall suspend all operations that further disturb such materials and 

C-6 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

immediately contact the AO. Operations shall not resume until written authorization to proceed is 

issued by the AO. 

7.	 Within five (5) working days, the AO will evaluate the discovery and inform the Operator of actions 

that will be necessary to prevent loss of significant cultural or scientific values. 

8.	 The Operator shall be responsible for the cost of any mitigation required by the AO. The AO will 

provide technical and procedural guidelines for the conduct of mitigation. Upon verification from the 

AO that the required mitigation has been completed, the Operator shall be allowed to resume 

operations. 

9.	 If any dead or injured threatened, endangered, proposed, or candidate animal species is located during 

construction or operation, the U.S. Fish and Wildlife Service's Wyoming Field Office (307-772­

2374), its law enforcement office (307-261 -6365), and the BLM Rawlins Field Office (307-328­

4200) shall be notified within 24 hours. If any dead or injured sensitive species is located during 

construction or operation, the Rawlins Field Office shall also be notified within 24 hours. 

10. If dead or injured raptors, big game, migratory birds, or unusual wildlife are observed on the project 

area, Operator personnel will contact the appropriate BLM and WGFD offices. Under no 

circumstances will dead or injured wildlife be approached or handled by Operator personnel. 

11. Operators shall notify the BLM immediately if raptors are found nesting on or within 1,200 feet of 

project facilities and assist the BLM as necessary in erecting artificial nesting structures (ANSs) as 

appropriate. The use of ANSs will be considered as a last resort for raptor protection. If nest 

manipulation or a situation requiring a "taking" of a raptor nest becomes necessary, a special permit 

will be obtained from the Denver USDI-FWS Office, Permit Section and will be initiated with 

sufficient lead time to allow for development of mitigation. Required corresponding permits will be 

obtained from the WGFD in Cheyenne. Consultation and coordination with the USDI-FWS and 

WGFD will be conducted for all protection activities relating to raptors. 

12. Operator and Operator’s sub-contracted personnel shall not intentionally harm or harass wild horses, 

other wildlife, or domestic livestock. 

13. ROW, mineral lease, mining claim, and permit holders shall monitor and control noxious and 

invasive weeds, according to an approved weed management plan, on project-disturbed areas and 

native areas infested as a direct result of the project. The control methods shall be in accordance with 

guidelines established by the EPA, BLM, state and local authorities. Prior to the use of pesticides, the 

Operator will obtain written approval from the AO - meaning an approved Pesticide Use Proposal 

form - showing the type and quantity of material(s) to be used, pest(s) to be controlled, method of 

application, etc. 

14. Pesticide Use Proposals shall be submitted to and approved by the BLM AO—Weed Coordinator, 

prior to any application of any herbicide on the BLM lands. Pesticide Use Proposals will be tiered to 

the approved Reclamation Plan/Weed Management Plan. 

15. Copies of daily Pesticide Application Records (required by the State of Wyoming) and Summary 

Herbicide Use Reports are due monthly to the BLM AO—Weed Coordinator. 

16. The Operator shall be responsible for the prevention and suppression of fires on public lands caused 

by its employees, contractors, or its subcontractors. During conditions of extreme fire danger, surface 

use operations may be either limited or suspended in specific areas, or additional measures may be 

required by the AO. Should a fire occur, it shall be immediately reported to this office by calling 307­

328-4200 and notifying the Fluid Minerals staff. 

17. Emissions of particulate matter from well pad, road, and other facility construction, operation, and 

reclamation activities will be minimized by application of water or other dust suppressants. Dust 

inhibitors (surfacing materials, dust suppressants, and water) will be used as necessary on locations 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-7 
APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

that present a fugitive dust problem. The use of chemical dust suppressants on public surface will 

require prior approval from the AO. 

18. If groundwater or permeable/porous subsoil or bedrock is encountered upon construction of the pad 

or pits, or upon drilling and completing shallow holes for surface conductor, rat/mouse holes, or water 

supply well, the Operator must immediately notify the AO’s Representative before proceeding. 

19. The Operator shall comply with the Hazardous Materials Management Plan/Summary in the RMP 

ROD (Appendix 32) and/or the appropriate EIS ROD, including requirements to transport, store, 

utilize, and dispose of hazardous substances. The Operator shall maintain a hazardous substances 

release contingency plan that shall include, among other things, provision to notify the AO in the 

event of any release of hazardous substances associated with project operations. Treatment chemicals 

may require additional storage and containment measures and facilities depending on chemical 

classification and hazard. 

20. If a portable sewage treatment facility is moved onto location, the well/lease Operator shall provide 

the BLM AO a copy of the facility Operator's notification letter to the Wyoming Department of 

Environmental Quality. Facility operations shall comply with BLM requirements, including 

unauthorized discharge notification and reclamation of disturbed surfaces. 

21. Only those hazardous wastes that qualify as exempt, under the Resource Conservation and Recovery 

Act (RCRA), Oil and Gas Exemption, may be disposed of in the reserve pit. Generally, oil or gas 

wastes are exempt if they: 

a) have been sent down hole and then returned to the surface during oil/gas operations 

involving exploration, development, or production, or 

b) have been generated during the removal of produced water or other contaminants from the 

oil/gas production stream. The term hazardous waste, as referred to above, is defined as a 

listed (40 CFR 261 -31 -33) or characteristic (40 CFR 261.20-24) hazardous waste under 

RCRA. 

22. Any spilled or leaked oil, produced water or treatment chemicals must be reported in accordance with 

NTL- 3A and immediately cleaned up in accordance with BLM requirements. This includes clean-up 

and proper disposition of soils contaminated as a result of such spills/leaks. The Operator shall 

segregate, treat, and/or bio-remediate contaminated soil materials as authorized via Sundry Notice 

(Form 3 160-5) or dispose of contaminated soils at a permitted waste facility. Treatment chemicals 

may require additional storage and containment measures and facilities depending on chemical 

classification and hazard. 

23. The Operator shall install an identification sign consistent with the requirements of 43 CFR 3 162.6 

immediately upon completion of the well pad/location construction operations. 

24. The Operator shall contain and remove all debris, unused equipment, and other waste materials not 

needed for production. Waste materials shall be disposed of at an approved disposal facility. 

25. Upon APD expiration, it is the responsibility of the Applicant/Operator to see that all stakes, flagging, 

posts or other materials placed on the locations and/or access roads, pipelines and associated rightsof-way are removed. Operator must immediately cease all operations associated with preparing to 

drill the well and begin final reclamation activities of all APD related disturbance, pursuant to the 

approved APD Conditions of Approval and to be completed within 6 months of the APD expiration 

date. 

26. Employee and contractor education will be conducted regarding wildlife laws. If violations are 

discovered on the project area, Operators will immediately notify the appropriate agency. Operators 

C-8 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

will implement policies designed to control off-site activities of personnel, that may result in littering 

or resource damage. 

27. Company and contractor employees operating motorized equipment will undergo training describing 

the types of wildlife in the area, the circumstances under which collisions are likely to occur and the 

measures that can be employed to minimize collisions. 

CONSTRUCTION 

1.	 All facilities on location that have the potential to leak/spill oil, glycol, methanol, produced water, 

condensate, or other fluids which may constitute a hazard to the environment, public health or safety 

(including, but not limited to, drain sumps, sludge holdings, and chemical containers), shall be within 

secondary containment, impervious to those fluids, exclusive of wildlife and livestock, with 

animal/bird escape capability, and able to contain a minimum of 110% of the volume of the largest 

storage vessel, respective to content, or 100% with at least one foot of freeboard, whichever is 

greater, so that any spill or leakage would not drain, infiltrate, or otherwise escape to ground water, 

surface water, or navigable waters before cleanup can be completed (within 72 hours). 

2.	 Construction over and/or immediately adjacent to existing pipelines shall be coordinated, and in 

accordance with, the relevant pipeline companies' policy. 

3.	 Fencing shall be installed around produced water, oil, and condensate tank batteries in order to help 

maintain the integrity of the surrounding containment structure and to prevent livestock and wildlife 

from entering the area in case of a leak or spill. 

4.	 All open vent stack equipment shall be designed and constructed to prevent entry by birds and bats 

and to discourage perching. 

5.	 The immediate repair/replacement (to BLM standards) of any range infrastructure breached, altered, 

or damaged by construction, drilling, or operation activities related to this APD shall be the 

responsibility of the Operator. All fence relocations will be in accordance with BLM approval. 

6.	 Construction, maintenance, and reclamation operations with frozen material or during periods when 

the soil material is saturated is expressly prohibited. If equipment, including licensed highway 

vehicles, creates ruts in excess of four (4) inches deep, the soil shall be deemed too wet to adequately 

support maintenance and/or heavy equipment. 

7.	 Accumulated snow present on the ground at the outset of construction, maintenance, or reclamation 

activities shall be removed before the soil is disturbed and piled downhill and/or downwind from the 

disturbed area. Equipment used for any non-construction snow removal operations will be equipped 

with 6" shoes to ensure blades do not remove topsoil or vegetation. Written approval must be 

obtained before snow removal related to a federal action but outside of designated disturbance areas is 

undertaken. 

8.	 When blading/removing snow, drifts/berms shall be constructed with a gap of 35 yards every 1/4 

mile, to allow unobstructed movement of wildlife, livestock and human activities. 

9.	 If right-of-way fencing is required, it will be kept to a minimum and the fences will meet the 

BLM/WGFD approval for facilitating wildlife movement. Wildlife-proof fencing will be used only to 

enclose areas that are potentially hazardous to wildlife species or reclaimed areas where it is 

determined that wildlife species are impeding successful vegetation establishment. 

10. Snow fences, if used, will be limited to segments of one-quarter mile or less. In addition, escape 

openings will be provided along roads in big game crucial winter ranges, as designated by the BLM, 

to facilitate exit of big game animals from snowplowed roads. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-9 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

11. Clearly remove, segregate, and delineate from all other spoils, all available topsoil from constructed 

locations and surface disturbances including areas of cut and fill. Stockpile and clearly identify 

topsoils at the site for use in reclamation on all areas of surface disturbance (well pads/locations, 

roads, pipelines, etc.). 

12. Plugs or embankments providing wildlife with access out of and across open pipeline trenches shall 

be installed, at minimum, every 1,320 linear feet along open pipeline trenches. 

13. No construction and/or reclamation shall block or change the natural course of any drainage, nor shall 

topsoil, waste, or fill material be deposited below high water lines in riparian areas, flood plains, or in 

natural drainage ways. The lower edge of soil or other material stockpiles will be located outside 

active floodplains. All spoils will be placed where they can be retrieved without creating additional 

surface disturbance and where they do not impede and/or contribute sediment to watershed and 

drainage flows. The Operator shall also reconstruct and stabilize stream channels, drainages, and 

ephemeral draws to exhibit similar hydrologic characteristics that were found in stable, naturally 

occurring and functioning systems. 

14. Drainage and run-on/runoff shall be diverted away from all new construction naturally or through the 

use of diversion ditches/berms and/or soil berms or stockpiles. All drainage structures shall 

approximate topographic contour lines, have a grade no greater than 0.5 – 1 percent, and shall release 

water onto natural undisturbed ground without causing additional and/or accelerated erosion. 

Drainage structures shall not discharge directly into/onto natural drainages/channels, and/or use riprap 

or other armoring to protect from erosion (BLM Manual 9113). Water-bars, waddles, hay bales, 

and/or silt fences shall be used as needed to reduce surface runoff velocity and promote upland 

sediment deposition, thus reducing drainage/channel sedimentation and erosion. 

15. Silt fences, if needed, would be installed after topsoil removal and before pad leveling begins and 

must remain in place until interim reclamation is complete and there is adequate vegetation present to 

stabilize the soil. Silt fences would be constructed in locations where surface erosion is evident or 

potential for surface erosion exists such as areas of steep slopes or highly erosive soils. Fences would 

be installed at the inside edge of disturbance. 

16. Silt fences would be constructed using metal posts that are at least 5 feet long with at least 2 feet in 

the ground (3 feet above ground) with 8 feet spacing if a wire re-enforcement backing is used or 6 

feet spacing if no wire backing is used. The fabric is to be toed into the ground at the base of the fence 

a minimum of 8 inches deep and an 18 inch overlap is required when splicing two fences together. 

The fabric is to be installed on the uphill side of the metal posts and attached to the posts at least 

every 6 inches along the length of the post. Silt fences are to be inspected at least once a month or 48 

hours after a rain storm event. If holes in the fence or undercutting of the fence are found, repair is 

required within 48 hours of discovery. When silt accumulates to a height equal to two-thirds the 

height of the fabric, the silt is to be cleaned out and deposited on the excess spoils pile. 

17. Sediment fences, straw wattles, erosion mats and/or hay bales should be used to minimize erosion and 

sediment transport on disturbance area. 

18. If temporary surface pipelines, as authorized by the AO, are used to transport water, they shall be 

placed/removed when the ground surface is dry. Surface blading prior to line placement is prohibited. 

The pipelines must be removed within 30 days after well completion (or determination of inactivity). 

19. Construction control stakes shall be placed as necessary to ensure construction of the well pad, topsoil 

stockpile, spoil pile, and outer limits of the area to be disturbed in accordance with the specifications 

outlined in the APD. The Operator shall assume full responsibility for protecting all stakes and 

offsetting any additional stakes or grades which may be necessary. 

C-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

20. All production facilities including but not limited to tanks, separators, dehydrators, meters, etc. would 

be co-located on nearby producing well locations, in accordance with an approved Sundry Notice of 

Intent for construction. All wells, above-ground structures, production equipment, tanks, transformers 

and insulators not subject to coloring requirements for safety would be painted the color of “non 

reflective Shale Green”. 

21. To protect the identified ferruginous hawk nests, Greater Sage-grouse leks and wintering big game 

habitat, the project proponent will install housing and/or muffler(s) around equipment that exceeds 55 

dBA (ES-7, 4-69, 4-157 AR EIS) 

22. Cathodic protection wells would be drilled on the existing well pad, placed so as not to interfere with 

re-contouring of cut and fill slopes during interim reclamation, designed and constructed to prevent 

commingling and contamination of water aquifers. The AO would be notified of any water flows at 

surface and the problem would be resolved promptly. 

23. All stacks, exhauster, or vent pipes shall have anti perch cones and vent covers to prevent bat or small 

bird entry and entrapment. 

ROADS 

1.	 All access roads and drainage control structures, whether existing or newly constructed, shall be both 

constructed to resource road standards and regularly maintained in a safe and usable condition as 

outlined in BLM Manual, Section 9113. A regular maintenance program may include, but is not 

limited to, blading, ditching, culvert installation, dust control, and gravel surfacing or other activities 

as specified by the AO. The Lessee and/or Operator shall enter into a maintenance agreement with all 

other "authorized users" of the common access road(s) to the well site. The costs of road maintenance 

in dollars, equipment, materials, labor, and other related expenses shall be shared proportionally 

among the "authorized users." Upon request, the AO shall be provided copies of any maintenance 

agreement or agreements. 

2.	 Access roads would be constructed to the BLM Road Standards in such manner as to minimize cuts 

and fills and minimize erosion and sedimentation and maximize reclamation, as determined during 

the onsite. 

3.	 Engineered Roads and/or culverts shall be designed in accordance with the Engineered Road 

Requirements, with four copies of the following information submitted to the BLM project NRS for 

approval, prior to construction. 

a.	 Plan, profile and typical cross section. 

b.	 Centerline stakes shall be placed in the field, with culvert locations marked on the centerline, for 

the BLM review before final design approval. In addition, slope stakes shall be placed at the top 

of the cut and the bottom of the fill for those portions of the road that are engineered. All 

roadways cuts and fills shall be designed to balance from earthwork within the ROW, or an 

approved borrow source. 

c.	 Perform a “hydrologic analysis” to design culverts sized to pass a 25-year precipitation event with 

no head developed at the culvert inlet. 

d.	 The submitted plans must be signed/certified by a professional engineer and will include any 

special notes for construction and cut/fill balance notes. 

4.	 All Operators and Operator's representative vehicles are restricted to authorized travel routes only and 

shall not use any other access route, e.g.; two-track roads, trails, and pipeline rights-of-way to access 

the drill/ell pad and any ancillary facilities. 

5.	 Two-track roads shall not be cut-off as a direct result of construction, maintenance, or reclamation of 

the well access road or associated well facilities, unless authorized by the BLM. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-11 
APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

6.	 Prior to construction, road(s) shall be surveyed and staked with construction control stakes set 

continuously along the centerline at maximum 100-foot intervals (less where needed to be intervisible) and at all tangent and curve control points, fence or utility crossings, and culverts. In addition 

to centerline stakes, slope stakes shall be placed at the top of the cut and the bottom of the fill for 

those portions of the road that are engineered. 

7.	 Before proposed road construction activities begin, the topsoil must be bladed to the side of the road 

and stockpiled. The topsoil stockpile shall be contoured so as to prevent water ponding or flow 

concentration. Once the borrow ditch and the cut slopes are constructed, cleared vegetative material 

and topsoil that is windrowed shall be spread back onto the cut/fill slopes of the road, removing any 

windrows or berms remaining at the edge of the road. 

8.	 The minimum travel-way width of the immediate access road will be 14 feet with turnouts at least 10 

feet in width. No structure will be allowed to narrow the road top. The inside slope will be 4: 1. The 

bottom of the ditch will be a smooth V with no vertical cut in the bottom. The outside slope will be 

2:1 or flatter. After the road is crowned and ditched with a .03-.05 ft/ft crown, the topsoil and 

windrowed vegetative material shall be pulled back down on the cut slope so there is no berm left at 

the top of the cut slope. Turnouts will be spaced at a maximum distance of 1000 feet and will be 

intervisible. If the access road crosses a floodplain, the ditch shall be flat-bottomed so as to provide 

material to raise the road, unless otherwise approved by the AO. 

9.	 If soils along the access road route are dry during road construction, use, and/or maintenance, fresh 

water shall be applied to the road surface to facilitate soil compaction and minimize soil loss as a 

result of wind erosion. 

10. Construction and surfacing of the new access road shall be complete prior to moving drilling 

equipment onto the well pad and the presence of heavy vehicular traffic. Compact the top foot of subgrade in even six (6) to eight (8) inch lifts to established standards, adding water as needed for 

compaction. Surface with an appropriate grade of gravel to a minimum depth of four (compacted) 

inches. 

11. All cattle guards shall be designed and maintained consistent with BLM standards and shall be a 

minimum of 16 feet wide and 8 feet long; set on either timber, pre-cast concrete, or cast-in-place 

concrete bases at right angles to the roadway. They shall have drop-down wings and an adjacent 16 

foot wide tubular bypass gate; not narrow the road surface; and have fence and end panels on either 

side constructed using 3 posts with “H” braces. 

12. All culverts shall be a minimum of 18 inches in diameter. Culverts shall have a minimum of 12" of 

fill or 1/2 the pipe diameter, whichever is greater, placed on top of the culvert, and shall be of length 

sufficient to allow at least 12" of culvert to extend beyond the toe of any slope. The inlet and outlet 

shall be set on grade. No rocks shall be used in the bed material and no rocks greater than 2" in 

diameter will be immediately adjacent to the culvert. The entire length of pipe shall be bedded on 

native material before backfilling, which shall be completed using unfrozen material and rocks no 

larger than two inches in diameter; compact the backfill evenly in 6" lifts on both sides of the culvert. 

A permanent marker shall be installed at both ends of the culvert to help prevent traffic from 

damaging the culvert. Additional culverts will be placed in the new access road as the need arises or 

as directed by the AO. 

13. Wing-ditches shall be staked and constructed at a slope of .5 to 1.0 percent down slope unless 

otherwise approved by the AO. All wing/drainage ditches and culverts shall be kept clear and free 

flowing, and shall also be maintained in accordance with the original construction standards. 

Drainage structures shall not discharge directly into/onto natural drainages/channels, and/or use riprap 

or other armoring to protect from erosion (BLM Manual 9113). 

C-12 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

14. Low water crossings shall be constructed perpendicular to the channel and at original channel 

elevation in a manner that will not block or restrict existing channel flow. Excavated material shall be 

stockpiled for use in reclamation of the crossings. 

PITS 

1.	 All oil and gas pits that could contain fracture/stimulation fluids, recycled pit fluids, or produced 

water, except those only containing fresh-water based constituents, are required to be lined with an 

impermeable (12 mil minimum with a permeability less than or equal to 1 X 10-7 cm/sec) liner. The 

liners shall be physically and chemically compatible with all substances which it may contact and 

shall be of sufficient strength and thickness to withstand normal installation and use, and installed so 

that it will not leak. The liner shall be installed over a smooth sub-grade, matting, or fill materials 

(e.g. sifted dirt, sand, or bentonite) free of pockets, loose rocks, and other objects that could damage 

the liner. 

2.	 The only fluids/waste materials which are authorized to go into reserve pits are RCRA-exempt 

exploration and production wastes. Any evidence of RCRA non-exempt wastes being put into the 

reserve pit may result in the BLM AO requiring specific testing and closure requirements. 

3.	 All pits are required to maintain a minimum of 2 feet of freeboard between the liquid level and the top 

of the liner. If operations cause fluid levels in pits to rise above the required freeboard, immediate 

notification shall be provided to the AO with concurrent steps taken to cease the introduction of 

additional fluids, until alternative containment methods can be approved. 

4.	 Flaring of gas into the reserve or completion pits will not be allowed without prior approval from the 

AO. Flaring into lined pits is prohibited. 

5.	 All pits shall be kept free of trash, debris, solid wastes, and other unauthorized waste materials 

including oil and liquid hydrocarbons. 

6.	 For the protection of livestock and wildlife, all pits and open cellars shall be fenced on all sides, with 

corner bracing, immediately upon construction. Reserve, flare, completion, and production pits shall 

be adequately fenced during and after drilling operations until pits are reclaimed so as to effectively 

keep out wildlife and livestock. Operator shall, within ten (10) days of discovery, remove any floating 

hydrocarbons from pit surface. Approved netting (mesh diameter no larger than one inch) is required 

over any pit that contains or is identified as containing hydrocarbons or hazardous substances (per 

RCRA 40 CFR Part 26 1 or CERCLA Section 10l (14) (E)). 

7.	 Pits shall be dried, backfilled, and closed within six (6) months from well completion (total depth) or 

well plugging. Pits must be void of all free fluids prior to backfilling. Pit trenching or squeezing is 

prohibited. Pits may be dewatered/dried in the following manner: natural evaporation, mechanical 

aeration, chemical and mechanical solidification (e.g. with fly ash, cement kiln dust, etc.) and/or 

hauled to an approved DEQ disposal site. The installation/operation of any sprinklers, misters, 

aerators, pumps, hoses, and related equipment shall ensure that water spray or mist does not drift 

outside of the pit. All other dewatering/drying, removal or disposal methods not listed in the APD and 

or COAs shall have prior written approval from the AO. 

8.	 Pits, once dry, shall be backfilled and compacted with a minimum cover of five (5) feet of soil, void 

of any topsoil, vegetation, large stones, rocks or foreign objects. The pit area shall be mounded to 

allow for settling and to promote positive surface drainage away from the pit. Before backfilling 

synthetically lined reserve pits, those liner portions remaining above the "mud line" shall be cut off as 

close to the top of the mud surface as possible and disposed of at an approved solid waste disposal 

facility. The pit bottom and remaining liner shall not be trenched, cut, punctured, or perforated. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-13 
APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

FLUIDS 

1.	 All storage, removal and disposal of produced water must be in accordance with and comply with 

Onshore Oil and Gas Order No. 7. Produced water must be disposed of at a permitted off-site 

commercial disposal facility, unless approved otherwise by the BLM AO. The onsite storage/disposal 

of produced water, in open pits, tinhorns, sumps, etc., is not authorized except as follows: 1) produced 

water from the well subsequent to drilling may be disposed of in the approved well site reserve pit 

(for up to 90 days), and/or 2) used for well drilling or completion, upon prior written approval from 

the AO via approved APD or Sundry. Produced water may be transported and used for 

drilling/completion operations from approved fee, state, or federal wells/leases to federal wells/leases 

within the developed field/unit and/or EIS area, subject to WOGCC and BLM approval. 

2.	 Pit drilling fluids may be transferred from a reserve pit at an approved federal well location to a lined 

reserve pit at another approved federal well location, for the purpose of drilling the well. 

Transfer/reuse shall only be permitted when transfer is by a lease Operator from one or more pits to 

another pit or pits on the Operator's federal lease/unit or adjacent federal lease. Unless approved by 

this APD, the transfer and reuse of pit drilling fluids shall require prior written approval from the AO, 

via a Sundry Notice (Form 3160-5). 

3.	 The AO may authorize the use of produced water or reuse of pit drilling fluids for drilling when: 1) 

surface casing has been set with fresh water through any and all possible fresh water zones, 2) use is 

for drilling/completion only, and 3) the receiving pit is lined. 

4.	 Pit fluids may be transferred by a lease Operator from one or more pits to another (lined) pit or pits on 

the Operator's federal lease/unit or adjacent federal lease, for the purpose of fluid consolidation and 

mechanical/chemical drying and disposal. The 6-month pit closure requirement shall apply. Unless 

approved by this APD, the transfer of pit fluids for consolidation/disposal shall require prior written 

approval from the AO, via a Sundry Notice (Form 3160-5). 

5.	 Initial Operator requests for the transport and use/reuse of produced water or pit drilling fluids or the 

transfer/consolidation of pit fluids shall include: 1) the potential locations/leases in which fluids are to 

be transferred to and from, and 2) the potential quantity to be moved. Requests shall be submitted for 

prior written approval from the AO via APD or Sundry Notice. Upon completion of transport, 

use/reuse or consolidation, the specific information on leases, units or locations and quantities 

transferred shall be submitted to the AO, via Sundry Subsequent Report. Transportation of fluids shall 

be along approved haul routes and authorized right-of-ways. Temporary surface pipelines may be 

authorized by the AO for the transfer of fresh water only, and NOT for produced water or pit fluids. 

6.	 Drilling water sources/supplies or any changes to drilling water sources/supplies, the fate of 

drilling/completion fluids, routes and means of fluid transportation/disposal, and location or method 

of produced water disposal requires prior written approval from the AO via approved APD, Sundry 

Notice or Right-of-way (ROW) as applicable. The drilling of water wells on federal lands shall 

require prior BLM approval via APD, Sundry, or ROW as applicable, in addition to State Engineer 

Office (SEO) approval. 

RECLAMATION 

1.	 A reclamation plan shall be submitted with each APD. The reclamation plan will address short-term 

stabilization to facilitate long-term reclamation. The reclamation plan is considered complete when all 

the reclamation requirements described in the BLM Reclamation Policy and the Rawlins RMP have 

been addressed, the techniques to meet the reclamation requirements are described in detail, and the 

BLM concurs with the reclamation plan. Surface disturbance will not be allowed until the reclamation 

plan is submitted, complete and approved by the BLM Authorized Officer. 

2.	 The Reclamation Plan shall include: 

C-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

a.	 Prior to any surface disturbing activities, vegetation inventories shall be conducted on each 

ecological site and they shall be mapped. At a minimum, vegetation inventories shall be 

conducted for basal cover and vegetative life form type and frequency (including individual 

invasive and noxious weed species) and include at least one photograph of each transect. An 

inventory of 100 to 400 points (depending on the amount and type of vegetative cover) using 

transects is highly recommended. The inventory method shall be included within the Reclamation 

Plan for approval. 

b.	 Prior to the completion of interim and final reclamation, the Operator shall sample and test soils 

for suitable surface and subsurface physical and chemical properties. At a minimum the soil shall 

be tested for texture, electrical conductivity, reactivity, pH and photographed. At least one 

photograph at each soil pit is required which also shows the vegetation community. These tests 

are to be used by the Operator to evaluate the suitability of the soils or seedbed for seed 

germination and potential for vegetative success under the approved reclamation plan. 

c.	 Prior to the completion of interim and final reclamation and seeding, the Operator shall submit to 

the BLM AO, via Sundry Subsequent Report (Form 3160-5), the results of all vegetative and soils 

surveys and tests. Should pre-disturbance and interim/final reclamation test results differ to the 

extent that the soil requires amendment(s) or the proposed seed mix requires modification to 

achieve the desired ecological and plant community, the Operator shall submit a revised 

reclamation plan via Sundry Notice of Intent (NOI) (Form 3160-5). The Sundry NOI shall outline 

any proposed soil amendments, treatments, additives or modifications, seed mix changes and 

other necessary revisions to the reclamation plan. 

d.	 Provisions to meet Standards and Guidelines for Healthy Rangelands (43 CFR 4180.1) and 

obtaining desired plant communities: 

http://www.blm.gov/wy/st/en/field_offices/Rawlins/range.html 

e.	 Mitigation for direct, indirect and cumulative livestock forage losses and impacts to livestock 

grazing (including impacts to livestock operations and production performance). This could 

include reclamation that would replace forage losses from surface disturbing activities, avoiding 

trailing routes and livestock gathering areas and seasonal restrictions (such as during lambing and 

calving in specific areas). 

3.	 The annual monitoring report shall be submitted by March 1 of each year. This report shall include 

reclamation and restoration efforts, including seeding/re-vegetation, invasive plant treatment/control, 

and soil stabilization and erosion prevention. The report shall be in accordance and consistent with 

the BLM and/or RFO Reclamation Policy, RMP (ROD) and Appendix 36, and the field/project level 

EA/EIS, as applicable. The yearly Operator report would include surface disturbance and reclamation 

data for the previous calendar year, utilizing the BLM RFO Disturbance (As-Built) Reclamation 

Database. The RFO surface disturbance and reclamation database, as well as information on the 

database and submission of the data, will be available at: 

http://www.blm.gov/wy/st/en/field_offices/Rawlins/oil_and_gas.html, or by contacting the RFO, 

Minerals and Lands, Supervisory Natural Resource Specialist/Physical Scientist at 307-328-4200 for 

further information. 

4.	 Reclamation plans and procedures, including those for seeding/re-vegetation and weed control, shall 

be modified and revised as necessary in order to achieve desired results and requirements. . 

5.	 Reclamation earthwork for interim and/or final reclamation shall be completed within six months of 

well completion or well plugging (weather permitting) and shall be consistent with the approved 

reclamation plan. Reclamation earthwork consists of: 

a.	 Backfilling pits, 

b.	 Re-contouring and stabilizing the well site, access road, cut/fill slopes, drainage channels, utility 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-15 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

and pipeline corridors and all other disturbed areas, to approximately the original contour, shape, 

function and configuration that existed before construction (any compacted backfilling activities 

would ensure proper spoils placement, settling and stabilization, 

c.	 Surface ripping, prior to topsoil placement, to a depth of 18-24 inches deep on 18-24 inch 

centers to reduce compaction, 

d.	 Final grading and replacement of topsoil, 

e.	 Surface-roughening and other techniques such as snow fencing to increase soil moisture 

retention and reduce compaction. Surface soil material can be pitted or roughened (not 

exceeding the applied topsoil depth) such that the entire reclamation area shall be uniformly
 

covered with depressions constructed perpendicular to the natural flow of water and/or 

prevailing wind, and
 

f.	 Seeding. 

6.	 Interim or final reclamation of all surface disturbed areas shall commence and be 

completed within one year of initial disturbance unless needed for well production 

operations, or otherwise approved by the AO. Interim reclamation for those areas not 

needed for production operations, including unnecessary access roads and pipeline 

right(s)-of-way, shall commence and be completed within six months of well completion. 

Stockpiled soils shall be distributed on disturbed areas and the production pad shall be as 

small as possible to allow for safe and prudent production operations. Some topsoil may 

be reserved for final reclamation. 

7.	 Any topsoil to be stockpiled for longer than one year shall be spread in layers not to exceed two 

feet maximum thickness, including topsoil underneath the pile and appropriately identified/signed 

as topsoil. These soil stockpiles shall be seeded with a prescribed seed mixture or sterile cover 

crop (included within the approved reclamation plan) and covered with mulch to reduce erosion 

and discourage weed invasion. 

8.	 Temporary fencing of the reclaimed well/facilities locations for the first two growing seasons after 

either interim or final seeding may be required to exclude livestock and wildlife and to help ensure 

better re-vegetation success. 

9.	 Any subsequent re-disturbance of reclamation shall be reclaimed within six months by the same 

means described in the approved reclamation plan. 

10. A Notice of Intent to Abandon (Form 3160-5) must be submitted and approved prior to any well 

abandonment activities. A joint inspection of the disturbed areas may be required and attended by 

the BLM and the Operator (or Operator's Designee), the primary purpose of which is to review and 

agree to the existing (or a new) abandonment and/or final reclamation plan. Earthwork must 

commence and be completed within six months from the date of plugging and abandonment and 

seeding no later than the next immediate growing season upon the completion of earthwork. All 

reclamation should be accomplished as soon as possible after the disturbance occurs, with efforts 

continuing until a satisfactory revegetation cover is established and the site is stabilized (three to 

five years) (RMP ROD Appendix 13-8). 

11. The Operator shall submit a Final Abandonment Notice (FAN), using Form 3160-5, to the AO 

when adequate reclamation of surface-disturbed areas has been completed. This FAN indicates 

that the Operator believes the location is considered ready for final inspection, with adequate 

vegetation cover and species diversity. Upon receipt of the FAN, the BLM will conduct a field 

inspection prior to releasing the bond liability for this location. 

12. Re-vegetation shall consist of species occurring in the surrounding natural vegetation and/or 

included in the approved seed mix as deemed desirable by the BLM or private surface owner in 

C-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

review and approval of the reclamation plan. Inter-seeding, secondary seeding, or staggered 

seeding may be required to accomplish re-vegetation objectives. The seed mixture(s) shall be 

planted in the amounts specified in pounds of pure live seed (PLS)/acre. There shall be no primary 

or secondary noxious weed seed in the seed mixture. Seed should be tested and the viability testing 

of seed would be done in accordance with State law(s) and within nine months prior to purchase. 

Commercial seed would be either certified or registered seed. The seed mixture container would be 

tagged in accordance with State law(s) and available for inspection by the AO. Since seeds are of 

different sizes and require different planting depths, the Operator would use the appropriate 

equipment to ensure that the seed mixture is correctly and uniformly planted over the disturbed 

area. Seed would be broadcast if drilling is not possible. When broadcasting the seed, the pounds 

per acre are to be doubled. The seeding would be repeated until a satisfactory stand is established 

as determined by the AO 

13. All practicable measures would be utilized to minimize erosion and stabilize disturbed soils on or 

adjacent to the disturbed and reclaimed area. There would be no evidence of mass-wasting, headcutting, large rills, gullies, down cutting or overall slope instability. Should the use or storage of 

hay, straw, or mulch be necessary, the Operator is required to use certified weed-free hay, straw 

and mulch on the BLM lands. 

14. Evaluation of growth and success shall be conducted as per RMP ROD (Appendix 36). If the 

treatment area is found, through Operator site-specific monitoring data, to be successfully 

reclaimed, Operator monitoring to confirm reclamation success shall continue for at least five 

growing seasons. The site shall also comply with additional management needs, including control 

of weed infestations. Success criteria as defined by the RMP is: criteria based on pre-disturbance 

surveys or surveys of adjacent undisturbed natural ground cover and species composition (which 

the Operator will do prior to disturbance) or eighty percent of pre-disturbance ground cover, ninety 

percent dominant species, no noxious weeds, and erosion features equal to or less than surrounding 

area. 

DRILLING 

No production from the wells drilled on this well pad location should start production UNTIL 

Sundry Notices granting variances from Onshore Orders 4 and 5 as related to commingling and 

allocations are approved. 

The drilling operations for this well shall be conducted in accordance with the Onshore Oil and Gas Order 

No. 2 as provided for in 43 CFR 3164.1. This includes the well control equipment and its testing, the mud 

system and associated equipment, and the casing and cementing. Any deviation from this approved drill 

plan pursuant to these conditions of approval requires prior approval of the petroleum engineer of the 

Rawlins Field Office. 

BOPE 

1.	 All BOPE shall meet or exceed the requirements of a 5M system as set forth in Onshore Oil and Gas 

Order No. 2. 

2.	 All choke lines from the drilling spool forward, shall be straight steel lines flanged at both ends, 

unless turns use tee blocks or are targeted with running tees and shall be anchored to prevent 

whip and reduce vibration. All choke lines shall have the same pressure rating as the BOP stack and 

choke manifold. The diameter of this line shall be a minimum of 2 inches for a 2M BOP system and a 

minimum of 3 inches for a 3M and greater BOP system. 

3.	 When an Operator chooses to use flexible lines for choke operations equipment they must: 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

a.	 Make a request for approval in advance of its use. The request must provide documentation 

showing the flexible hose was design specifically for the purposes of choke operations. 

b.	 The request for approval must include the Manufacturer's technical specifications for the flexible 

hose(s) under consideration. Specifications must include as a minimum: 

1) The smallest internal diameter of any section or part of the flexible hose assembly. 

2) The rated working pressure and temperature of the flexible hose assembly. 

3) The Minimum Bend Radius (MBR) at rated working pressure.
 

c.	 Manufacturer's technical specification must be kept on site and available for inspection at all 

times. Flexible hoses once approved and installed must match the original manufacturer's 

technical specifications regarding all stated dimensions and ratings. Flexible hoses which have 

been altered, repaired, or remanufactured in any way from their original specification without 

approval or certification from the original manufacturer will not be allowed. If the specifications 

are not available on site or the hose does not match the specifications, operations may be 

shut down until correction is accomplished. 

d.	 Each flexible hose must be marked/stamped by the manufacturer with the following information 

clearly legible and accessible on the steel sections of each end of the flexible hose (end fittings, 

couplers, flanges, stiffeners, etc.): 

1) Name or identification of the manufacturer. 

2) Serial number. 

3) The internal diameter of the flexible hose assembly. 

4) The rated working pressure of the flexible hose assembly. 

e.	 Flexible hoses must be firmly anchored to prevent excessive whip or vibration. Anchors must be 

constructed in a manner capable of withstanding whip and vibration given the rated working 

pressure and flow rates of the well control equipment. 

1)	 Anchors must be attached to the flexible portion of the hose and not to the "metal end 

assemblies" (e.g. hubs, flanges, stiffeners, etc.) 

2)	 Flexible hoses of twenty (20) feet or more in total length must be supported in order to 

keep the hose fairly level and secure from excessive movement. Leveling support locations 

must also be anchored adequately to withstand whip and vibration under rated working 

pressures and rated flowing conditions. 

3)	 Each and every bend in the flexible hoses exceeding 45' must be anchored. 

f.	 Use, operation, and maintenance of flexible hoses will comply fully with the manufacturer's 

specifications unless otherwise specified by the AO. 

g.	 Minimum diameters for choke lines will comply with the requirements of Onshore Order No. 2, 

III.A.2.a. 

h.	 Flexible hose end connections will meet all minimum requirements of Onshore Order No. 2. For 

example 3M systems and above require "All BOPE connections subjected to well pressure shall 

be flanged, welded, or clamped". 

i.	 Flexible hoses used in Hydrogen Sulfide (H2S) operations must provide proof the hose is 

approved by the manufacturer for use in this type of environment. 

j.	 Flexible hoses which are deformed (kinks, flattened areas, dents, significant surface abrasions or 

wear, permanent bends, etc) from the manufacturer's design and operational specification will be 

replaced upon discovery. 

k.	 It is the intent of the BLM in Wyoming to implement the Reaffirmed 2001 API publication 

(SPEC 16C) standard for Flexible choke hoses as a uniform requirement within the next three 

C-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

years. Operators during routine maintenance or replacement of these hoses may want to consider 

hoses which can meet the API (SPEC 16C) standard. 

4.	 A Form 3160-5 (subsequent Report Sundry Notice) shall be submitted to the AO's 

representative within five (5) working days following the test reporting the test results. The 

results reported will be a copy of the third party BOP test report including time and pressure 

charts, accumulator tests, notes/results made while performing the test, and recordation of 

any repair of BOP equipment made. 

Casing and Cementing 

1.	 For all 5M BOPE systems or greater, a pressure integrity test of each casing shoe shall be performed. 

The formation at the casing shoe shall be tested to a minimum of the mud weight equivalent 

anticipated to control the formation pressure to the next casing depth or at total depth of the well. This 

test shall be performed before drilling more than 20 feet of new hole. 

2.	 Pea Gravel or other material shall not be used to fill up around the surface casing in the event cement 

fall back occurs. 

3.	 A Form 3160-5 (Subsequent Report Sundry Notice), along with a copy of the service company's 

materials ticket and job log shall be submitted to this office within 5 working days following the 

running and cementing of all casing strings. 

4.	 Any change in the casing and cement design will be approved by the AO prior to the running of the 

casing string and/or cementing. 

5.	 No freshly hard-banded rough carbide pipe/collars will be rotated in the surface casing. 

Mud Program 

1.	 Drilling of the surface casing will occur with fresh water only. 

2.	 If a temporary surface pipeline is used to transport drilling water, the pipeline shall be laid and 

removed when the ground surface is dry so as to minimize surface disturbance. No blading or other 

alteration of the ground surface shall be allowed. 

Directional Drilling 

1.	 Per 43 CFR 3160.0-9 and 3162.4-2 for all wells drilled directionally, as Operator, you will be 

required to file with the Well Completion Report, Form 3160-4, a Certified Directional Survey. 

2.	 This Certified Directional Survey, required by 1) above, will include a Directional Survey 

Certification Form as certified by the directional contractor and the Operator Bottom Hole Location 

Certification Form as specified in the Wyoming Oil & Gas Conservation Commission (WOGCC) 

letter to All Wyoming Oil and Gas Operators dated October 15,2009, as may be amended from time 

to time. 

3.	 The requirements for a complete Certified Directional Survey are the same as found in the attachment 

to WOGCC letter to All Wyoming Oil and Gas Operators dated October 15, 2009, as may be 

amended from time to time. 

Other 

1.	 In the event down hole operations threaten to or cause fluid levels in the reserve pit to encroach on the 

required 2-foot freeboard, immediate notification shall be provided to the AO with concurrent steps 

taken to minimize the introduction of additional fluids until alternative containment methods can be 

approved. 

2.	 Rat and mouse holes (or any sub-grade excavations for drilling operations) shall be filled and 

compacted, with appropriate native materials, immediately upon release of the drilling rig from the 

location. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-19 
APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

3.	 Any permanent plug placed in the well during drilling and/or completion operations must have prior 

approval of the AO. 

4.	 As provided in NTL4A, gas produced from this well may not be vented or flared beyond an initial 

test period, 30 days or 50 MMcf, whichever first occurs, without approval of the AO. 

5.	 Drill Stem Tests shall meet or exceed the requirements set forth in Onshore Oil and Gas Order No. 2. 

6.	 All usable water, hydrocarbon and other mineral zones must be protected. 

7.	 Pursuant to Onshore Oil and Gas Order No. 2.III.B.l .e. and the Rules and Regulations of the 

Wyoming Oil and Gas Conservation Commission (Chapter 3, Section 22.(a) (i)), the Operator shall 

report all fresh water flows encountered while drilling to the AO (Petroleum Engineer) prior to 

the running the next string of casing. The reported information shall include a) well name, number 

and location, b) the date the water flow was encountered, c) depth at which the water flow was 

encountered and d) estimated water flow rate into the well bore. The Operator shall file a Form 3 160­

5 (Subsequent Report Sundry Notice) of this same information within 30 days of releasing the drilling 

rig. 

8.	 Open hole logs consisting of deep, medium and shallow resistivity curves, a porosity log and gammaray and SP curves shall be run at TD to at least 50' above any zone which may be considered to be 

productive of hydrocarbons. 

9.	 Completion Report: In accordance with 43 CFR 3160, Form 3160-4 (Well Completion or 

Recompletion Report and Log) must be submitted to the AO within 30 days after completion of the 

well or after completion of operations being performed, whether the well is completed as a dry hole 

or as a producer. Copies of all open hole and cased hole logs, core descriptions, core analyses, well 

test data, geologic summaries, sample descriptions, daily drilling reports, daily completion reports, 

formation test reports, stimulation reports, directional survey (if applicable), and all other surveys or 

data obtained and compiled during the drilling, completion, and/or work over operations, shall be 

included with Form 3160-4. Copies of all logs, as noted above, shall be submitted to this office on 

a compact disc in a ".las” digital file format and shall have a precision readout increment of 0.5 

feet. Any Mud Log copy submitted to this office shall be in a ".tif” format. 

10. Well Abandonment: In the event abandonment of the hole is desired, oral approval may be granted 

by the AO (Petroleum Engineer), but must be followed within 5 days with a Form 3160-5 (Sundry 

Notice of Intent to Abandon) which will give the complete plan of operation that will be utilized in 

the plugging. Unless the plugging is to take place immediately upon receipt of the oral approval, the 

AO (Petroleum Engineer) must be notified at least 24 hours in advance of the plugging of the well in 

order that this office can witness the plugging operation. Failure to obtain approval prior to 

commencement of abandonment operations shall result in immediate assessment under 43 CFR 

3163.1 (b)(3). The following will occur if the well is abandoned: 

a.	 In order to reduce the visual impact of the reclaimed well site, the casing shall be cut-off at the 

base of the cellar or 3 feet below the final restored ground level (whichever is deeper). The well 

bore shall then be covered with a metal plate at least 1/4 inch thick and welded in place. On the 

metal plate shall the following information be permanently inscribed: i) company/Operator name, 

ii) lease number, iii) well name/number, and iv) well location description to the nearest quarterquarter section (40 acres). 

b.	 A GPS re-verification and certification of the abandoned well location shall be made for 

coordinates of degrees latitude and longitude with accuracy to the sixth decimal place. This well 

location re-verification shall be noted on the Subsequent Report Sundry Notice of Abandonment. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

c.	 A temporary steel fence post with an attached placard indicating the well name/number and 

location shall be placed adjacent to the well bore until final well site reclamation has been 

performed and the Final Abandonment Notice (FAN) is approved. 

d.	 Within 30 days following completion of the well abandonment, you shall file with this 

office,subsequent Report of Abandonment (Form 3 160-5). To be included with this report is 

where the plugs were placed, volumes of cement used, well bore schematic as plugged, along 

with copies of all service company job log and service tickets. 

The Operator shall promptly plug and abandon each newly completed, re-completed or producing 

well which is not capable of producing in paying quantities. No well may be temporarily abandoned 

for more than 30 days without prior approval of the AO. When justified by the Operator, the AO may 

authorize additional delays, no one of which may exceed an additional 12 months. Upon removal of 

drilling or producing equipment from the site of a well which is to be permanently abandoned, the surface 

of the lands disturbed shall be reclaimed in accordance with a plan first approved or prescribed by the AO 

or per the reclamation conditions of approval stated herein. 

SITE SPECIFIC 

Additional COAs are usually included with the above to reflect requirements that apply to local 

conditions, such as seasonal wildlife restrictions, special surveys, specific constraints on road or well pad 

location or construction, and/or additional reclamation requirements. 

RIGHT-OF-WAY TERMS AND CONDITIONS 

In the process of acquiring permission to obtain a right-of-way, users submit a Form SF-299 to the BLM 

Field Office that manages the public lands where their proposed project is located. Included with the 

Form SF-299 are: 

	 a Plan of Development that contains a description of the proposed project (map, location, details of 

construction, and methods for containment and disposal of waste material), geologic data, expected 

hazards, and proposed mitigation measures to address such hazards; and 

	 a reclamation plan, which includes a weed management plan. 

When the BLM has completed the necessary environmental and technical review of the proposal, the 

BLM may approve the right-of-way as submitted or, more typically, approve the right-of-way subject to 

terms and conditions (T&C) on a grant. 

T&C are attached to an approved grant to ensure environmental protection, safety, and/or conservation of 

the mineral resource. They arise from a variety of controlling authorities such as Title V of the Federal 

Land Policy and Management Act of October 21, 1976 (FLPMA), Section 28 of the Mineral Leasing Act 

of 1920 (MLA), the National Environmental Policy Act (NEPA), the Endangered Species Act (ESA), and 

the National Historic Preservation Act (NHPA). The T&C attached to a grant can be general in nature or 

site-specific, and thus will vary from one BLM Field Office to another. Often the Field Office RMP 

provides either a listing of potential T&C or the BMPs that might guide development of site-specific 

T&C in that area. They can address topics as wide-ranging as protection of wildlife habitat or 

archeological and paleontological sites, noise reduction, wildfire suppression, or management of invasive 

species. Following is a master list of T&C that are used in the Rawlins Field Office when considering a 

right-of-way. The list is adapted as needed for site-specific use. Many of the items listed will not be used 

on a specific grant if not warranted. If, on the other hand, conditions call for requirements that are not on 

the list, BLM specialists can add new T&C. The list is presented in the standard format used for 

attachment to an approved grant. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

FORM 2800-14 

(August 1985) 

Issuing Office 

Rawlins Field Office 

UNITED STATES 

DEPARTMENT OF THE INTERIOR 

BUREAU OF LAND MANAGEMENT 

RIGHT-OF-WAY GRANT 

SERIAL NUMBER WYW-XXXXXX 

1. A right-of-way is hereby granted pursuant to Section 28 of the Mineral Leasing Act of 1920, as amended (30 

U.S.C. 185). 

A right-of-way is hereby granted pursuant to Title V of the Federal Land Policy and Management Act of October 

21, 1976 (90 Stat. 2776; 43 U.S.C. 1761). 

2. Nature of Interest: 

a.	 By this instrument, the holder: 

ABC ROW Company
 

PO Box 123 

Somewhere, ST XXXXX 

receives a right to construct, operate, maintain, and terminate a/an natural gas pipeline; powerline, well 

pad, compressor site, access road, etc. on public lands described as follows: 

T. 00 N., R. 99 W., 6th P.M., County, Wyoming;
 

section 37: Lot 83, N1⁄2SW1⁄4;
 

section 38: SW1⁄4NE1⁄4, N1⁄2SE1⁄4. 

b.	 The right-of-way or permit area granted herein is XX feet wide, XX feet long and contains XX acres, more 

or less. If a site type facility, the facility contains XX acres. 

c.	 This instrument shall terminate on December 31, 20XX unless, prior thereto, it is relinquished, abandoned, 

terminated, or modified pursuant to the terms and conditions of this instrument or of any applicable 

Federal law or regulation. 

d.	 This instrument may be renewed. If renewed, the right-of-way or permit shall be subject to the regulations 

existing at the time of renewal and any other terms and conditions that the authorized officer deems 

necessary to protect the public interest. 

e.	 Notwithstanding the expiration of this instrument or any renewal thereof, early relinquishment, 

abandonment, or termination, the provisions of this instrument, to the extent applicable, shall continue in 

effect and shall be binding on the holder, its successors, or assigns, until they have fully satisfied the 

obligations and/or liabilities accruing herein before or on account of the expiration, or prior termination, of 

the grant. 

3. Rental: 

For and in consideration of the rights granted, the holder agrees to pay the Bureau of Land Management 

fair market value rental as determined by the authorized officer unless specifically exempted from such 

payment by regulation. Provided, however, that the rental may be adjusted by the authorized officer, 

whenever necessary, to reflect changes in the fair market rental value as determined by the application of 

sound business management principles, and so far as practicable and feasible, in accordance with 

comparable commercial practices. 

4. Terms and Conditions:

 a.	 This grant or permit is issued subject to the holder's compliance with all applicable regulations contained 

in Title 43 Code of Federal Regulations part 2880. 

This grant or permit is issued subject to the holder's compliance with all applicable regulations contained 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

in Title 43 Code of Federal Regulations part 2800. 

b. Upon grant termination by the authorized officer, all improvements shall be removed from the public lands 

within 90 days, or otherwise disposed of as provided in paragraph (4)(d) or as directed by the authorized 

officer. 

c. Each grant issued for a term of 20 years or more shall, at a minimum, be reviewed by the authorized 

officer at the end of the 20th year and at regular intervals thereafter not to exceed 10 years. Provided, 

however, that a right-of-way or permit granted herein may be reviewed at any time deemed necessary by 

the authorized officer. 

d. The stipulations, plans, maps, or designs set forth in Exhibits A (Map) and B (Plan of Development) 

attached hereto, are incorporated into and made a part of this grant instrument as fully and effectively as if 

they were set forth herein in their entirety. 

e. Failure of the holder to comply with applicable law or any provision of this right-of-way grant or permit 

shall constitute grounds for suspension or termination thereof. 

f. The holder shall perform all operations in a good and workmanlike manner so as to ensure protection of 

the environment and the health and safety of the public. 

g. The holder shall comply with all Federal, State, and local regulations whether or not specifically 

mentioned within this grant. 

h. No surface disturbing activities shall take place on the subject right-of-way until the associated APD is 

approved. The holder will adhere to special stipulations in the Surface Use Program of the approved APD, 

relevant to any right-of-way facilities.

 i. The holder shall construct, operate, and maintain the facilities, improvements, and structures within this 

right-of-way in strict conformity with the plan of development which was approved and made part of this 

grant. Any relocation, additional construction, or use that is not in accord with the approved plan of 

development, shall not be initiated without the prior written approval of the authorized officer. A copy of 

the complete right-of-way grant, including all stipulations and approved plan of development, shall be 

made available on the right-of-way area during construction, operation, and termination to the authorized 

officer. Noncompliance with the above will be grounds for an immediate temporary suspension of 

activities if it constitutes a threat to public health and safety or the environment. 

j. The holder shall protect all survey monuments found within the right-of-way. Survey monuments include, 

but are not limited to, General Land Office and Bureau of Land Management Cadastral Survey Corners, 

reference corners, witness points, U.S. Coastal and Geodetic benchmarks and triangulation stations, 

military control monuments, and recognizable civil (both public and private) survey monuments. In the 

event of obliteration or disturbance of any of the above, the holder shall immediately report the incident, in 

writing, to the authorized officer and the respective installing authority if known. Where General Land 

Office or Bureau of Land Management right-of-way monuments or references are obliterated during 

operations, the holder shall secure the services of a registered land surveyor or a Bureau cadastral surveyor 

to restore the disturbed monuments and references using surveying procedures found in the Manual of 

Surveying Instructions for the Survey of the Public Lands in the United States, latest edition. The holder 

shall record such survey in the appropriate county and send a copy to the authorized officer. If the Bureau 

cadastral surveyors or other Federal surveyors are used to restore the disturbed survey monument, the 

holder shall be responsible for the survey cost. 

k. Any cultural and/or paleontological resource (historic or prehistoric site or object) discovered by the 

holder, or any person working on his behalf, on public or Federal land shall be immediately reported to the 

authorized officer. Holder shall suspend all operations in the immediate area of such discovery until 

written authorization to proceed is issued by the authorized officer. An evaluation of the discovery will be 

made by the authorized officer to determine appropriate actions to prevent the loss of significant cultural or 

scientific values. The holder will be responsible for the cost of evaluation and any decision as to proper 

mitigation measures will be made by the authorized officer after consulting with the holder. 

l. Weeds shall be controlled on project disturbed areas and native areas infested as a direct result of the 

project. The control methods shall be in accordance with the approved weed management plan (to be 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

submitted by the Holder), and guidelines established by the EPA, BLM, state and local authorities. Prior 

to the use of pesticides, the holder will obtain written approval from the BLM Authorized Officer—Weed 

Coordinator (meaning an approved Pesticide Use Proposal form). 

m.	 To further reduce the spread of invasive and noxious weeds following construction activities, inspections 

for weeds will be conducted each year along with revegetation monitoring during the first five years 

following construction. Thereafter, weed surveys would be conducted at least once every three years at 

appropriate times as directed by the authorized officer, for the life of the project. Reports of these surveys 

will be submitted to the authorized officer within 30 days of the surveys. 

n.	 The holder of this right-of-way grant or the holder's successor in interest shall comply with Title VI of the 

Civil Rights Act of 1964 (42 U.S.C. 2000d et seq.) and the regulations of the Secretary of the Interior 

issued pursuant thereto. 

o.	 The holder shall contact the authorized officer at least 48 hours (two days) prior to the anticipated start of 

construction and/or any surface disturbing activities. This can be done by logging into: 

http://www.blm.gov/wy/st/en/field_offices/Rawlins/oil_and_gas.html. Then click on Right-of-Way 

Construction Notice and fill in the form and submit it. Or, you may call the authorized officer. The 

authorized officer may require and schedule a preconstruction conference with the holder prior to the 

holder’s commencing construction and/or surface disturbing activities on the right-of-way. The holder 

and/or his representative shall attend this conference. The holder’s contractor, or agents involved with 

construction and/or any surface disturbing activities associated with the right-of-way, shall also attend this 

conference to review the stipulations of the grant including the plan of development. 

p.	 The holder shall have, on-site, a qualified individual (not the dirt contractor) to serve as Compliance 

Coordinator. This individual will be responsible for assuring that all requirements of the Plan of 

Development and appropriate Additional Terms and Conditions are applied. The holder must provide 

the name of the Compliance Coordinator to the authorized officer prior to any surface disturbance.

 q.	 No construction or routine maintenance activities shall be performed during periods when the soil is too 

wet to adequately support construction equipment. If such equipment creates ruts in excess of four (4) 

inches deep, the soil shall be deemed too wet to adequately support construction equipment. 

r.	 Within 90 days of completion, the holder will submit to the authorized officer, as-built drawings and a 

certification of construction verifying that the facility has been constructed (and tested) in accordance with 

the design, plans, specifications, and applicable laws and regulations.

 s.	 The holder shall conduct all activities associated with the construction, operation, and termination of the 

right-of-way within the authorized limits of the right-of-way. 

t.	 The holder shall inform the authorized officer within 48 hours of any accidents on federal lands that 

require reporting to the Department of Transportation as required by 49 CFR Part 195. 

u.	 The holder(s) shall comply with all applicable Federal laws and regulations existing or hereafter enacted or 

promulgated. In any event, the holder(s) shall comply with the Toxic Substances Control Act of 1976, as 

amended (15 U.S.C. 2601, et seq.) with regard to any toxic substances that are used, generated by or stored 

on the right-of-way or on facilities authorized under this right-of-way grant. (See 40 CFR, Part 702-799 

and especially, provisions on polychlorinated biphenyls, 40 CFR 761.1-761.193.) Additionally, any 

release of toxic substances (leaks, spills, etc.) in excess of the reportable quantity established by 40 CFR, 

Part 117 shall be reported as required by the Comprehensive Environmental Response, Compensation and 

Liability Act of 1980, Section 102b. A copy of any report required or requested by any Federal agency or 

State government as a result of a reportable release or spill of any toxic substances shall be furnished to the 

authorized officer concurrent with the filing of the reports to the involved Federal agency or State 

government. 

v.	 The holder of Right-of-Way No. WYW-XXXXXX agrees to indemnify the United States against any 

liability arising from the release of any hazardous substance or hazardous waste (as these terms are defined 

in the Comprehensive Environmental Response, Compensation and Liability Act of 1980, 42 U.S.C. 9601, 

et seq. or the Resource Conservation and Recovery Act of 1976, 42 U.S.C. 6901 et seq.) on the right-ofway (unless the release or threatened release is wholly unrelated to the right-of-way holder's activity on the 

right-of-way. This agreement applies without regard to whether a release is caused by the holder, its agent, 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

or unrelated third parties. 

w.	 In the event that the public land underlying the right-of-way (ROW) encompassed in this grant, or a 

portion thereof, is conveyed out of Federal ownership and administration of the ROW or the land 

underlying the ROW is not being reserved to the United States in the patent/deed and/or the ROW is not 

within a ROW corridor being reserved to the United States in the patent/deed, the United States waives any 

right it has to administer the right-of-way, or portion thereof, within the conveyed land under Federal laws, 

statutes, and regulations, including the regulations at 43 CFR Part [2800][2880], including any rights to 

have the holder apply to BLM for amendments, modifications, or assignments and for BLM to approve or 

recognize such amendments, modifications, or assignments. At the time of conveyance, the 

patentee/grantee, and their successors and assigns, shall succeed to the interests of the United States in all 

matters relating to the right-of-way, or portion thereof, within the conveyed land and shall be subject to 

applicable State and local government laws, statutes, and ordinances. After conveyance, any disputes 

concerning compliance with the use and the terms and conditions of the ROW shall be considered a civil 

matter between the patentee/grantee and the ROW Holder. 

x.	 A litter policing program shall be implemented by the holder, and approved of in writing by the authorized 

officer, which covers all roads and sites associated with the right-of-way. 

y.	 For the purpose of determining joint maintenance responsibilities, the holder shall make road use plans 

known to all other authorized users of the road. Holder shall provide the authorized officer, within 30 days 

from the date of the grant, with the names and addresses of all parties notified, dates of notification, and 

method of notification. Failure of the holder to share proportionate maintenance costs on the common use 

access road in dollars, equipment, materials, or manpower with other authorized users may be adequate 

grounds to terminate the right-of-way grant. The determination as to whether this has occurred and the 

decision to terminate shall rest with the authorized officer. Upon request, the authorized officer shall be 

provided with copies of any maintenance agreement entered into. Authorized users are as follows: 

name(s) and address(s)

 z.	 Prior to termination of the right-of-way, the holder shall contact the authorized officer to arrange a pretermination conference. This conference will be held to review the existing reclamation plan and 

termination provisions of the grant or agree to a new updated reclamation plan. 

5. Additional Terms and Conditions: 

Wildlife Resources*:

 a. Surface disturbing and disruptive activities potentially disruptive to nesting raptors are prohibited from 

February 1 to July 15. (Golden eagle, barn owl, red-tailed hawk, great-horned owl, other raptors) 

Surface disturbing and disruptive activities potentially disruptive to nesting raptors are prohibited April 1 

to July 31. (Osprey, merlin, sharp-shinned hawk, kestrel, prairie falcon, northern harrier, Swainson’s hawk, 

Cooper’s hawk) 

Surface disturbing and disruptive activities potentially disruptive to nesting raptors are prohibited March 1 

to July 31. (Short-eared owl, long-eared owl, ferruginous hawk, peregrine falcon, screech owl) 

Surface disturbing and disruptive activities potentially disruptive to nesting raptors are prohibited April 15 

to September 15. (Burrowing owl) 

Surface disturbing and disruptive activities potentially disruptive to nesting raptors are prohibited April 1 

to August 31. (Goshawk) 

[****Realty Specialists-Please remove raptor species from the applied stipulation, for reference only****] 

Please note that the above raptor stipulation(s) may differ from past raptor stipulations as a result of 

the signing of the Record of Decision for the new Rawlins Resource Management Plan on December 

24, 2008. 

Surface disturbing and disruptive activities potentially disruptive to Western yellow-billed cuckoos are 

prohibited within one-half mile of identified habitat from April 15 to August 15 for the protection of 

nesting Western yellow-billed cuckoos. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

Surface disturbing and disruptive activities within big game crucial winter range are prohibited during the 

period of November 15 to April 30. 

Surface disturbing activities or occupancy are prohibited on and within one-quarter mile of the perimeter 

of an occupied greater sage-grouse or sharp-tailed grouse lek. Disruptive activities are prohibited between 

6pm-9am, March 1-May 20 on and within one-quarter mile of lek perimeter. 

Surface disturbing and disruptive activities potentially disruptive to delineated greater sage-grouse/sharptailed grouse winter concentration areas are prohibited during the period of November 15-March 14. 

Avoid surface disturbing and disruptive activities, geophysical surveys, and organized recreational 

activities (events) that require a special use permit within 2 miles of the perimeter of an occupied greater 

sage-grouse lek, within 1 mile of the perimeter of a sharp-tailed grouse lek, or in greater sage-grouse and 

sharp-tailed grouse nesting and early brood rearing habitat from March 1 to July 15. 

Surface disturbing and disruptive activities are prohibited during the period of May 1 to June 30 for the 

protection of elk calving areas. 

Surface disturbing and disruptive activities located in potential mountain plover habitat are prohibited 

during the reproductive period of April 10 to July 10 for the protection of nesting plover. Additional 

protection measures may be applied if this area is later determined to be within occupied habitat. 

The project is located within an area where mountain plover broods and/or adults have been found. 

Additional protection measures that will be applied are attached. 

Any exceptions to this/these requirements must have prior written approval from the authorized officer. 

*Please be advised that due to limits on the available time of qualified personnel, the 

unpredictability of wildlife, and future weather conditions, requests for exceptions to impending 

wildlife stipulations will only be considered in the event of extraordinary and unavoidable 

occurrences over which the company has little or no control. Additionally, construction of the 

facility needs to be started in a time frame which would allow for reasonably normal completion 

prior to the beginning date of wildlife protection stipulations.

 b.	 If any dead or injured threatened, endangered, proposed, or candidate animal species is located during 

construction or operation, the U.S. Fish and Wildlife Service’s Wyoming Field Office (307-772-2374), 

their law enforcement office (307-261-6365), and the BLM Rawlins Field Office (307-328-4200) shall be 

notified within 24 hours. If any dead or injured sensitive species is located during construction or 

operation, the BLM Rawlins Field Office shall also be notified within 24 hours. 

c.	 The holder and holder’s sub-contracted personnel shall not intentionally harm or harass wild horses, other 

wildlife, or domestic livestock. 

Cultural Resources: 

a. 

AAAA Resources: 

a. 

BBBB Resources: 

a. 

CCCC Resources: 

a. 

Construction: 

a.	 All design, material, and construction, operation, maintenance, and termination practices shall be in 

accordance with safe and proven engineering practices. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

b. The holder shall provide for the safety of the public entering the right-of-way. This includes, but is not 

limited to barricades for open trenches, flagmen/women with communication systems for single-lane roads 

without intervisible turnouts, and attended gates for blasting operations. 

c. The holder shall survey and clearly mark the centerline and/or exterior limits of the right-of-way. 

d. Construction sites shall be maintained in a sanitary condition at all times; waste materials at those sites 

shall be disposed of promptly at an appropriate waste disposal site. "Waste" means all discarded matter 

including, but not limited to, human waste, trash, garbage, refuse, oil drums, petroleum products, ashes, 

and equipment. 

e. Construction over and/or immediately adjacent to existing pipelines shall be coordinated, and in 

accordance with, the relevant pipeline companies’ policy. 

f. Construction-related traffic shall be restricted to routes approved by the AO. New access roads or crosscountry vehicle travel will not be permitted unless prior written approval is given by the AO. Authorized 

roads used by the holder shall be rehabilitated or maintained when construction activities are complete as 

approved by the AO.

 g. Existing roads and trails on public lands that are blocked as the result of the construction project shall be 

rerouted or rebuilt as directed by the AO. 

h. Fences, gates, and brace panels shall be reconstructed to appropriate Bureau standards and/or 

specifications as determined by the AO. 

i. When construction activity in connection with the right-of-way breaks or destroys a natural barrier used 

for livestock control, the gap, thus opened, shall be fenced to prevent the drift of livestock. The subject 

natural barrier shall be identified by the AO and fenced by the holder as per instruction of the AO.

 j. Accumulated snow present on the ground at the outset of construction, maintenance, or reclamation 

activities shall be removed before the soil is disturbed and piled downhill from the disturbed area. 

Equipment used for any non-construction snow removal operations will be equipped with 6” shoes to 

ensure blades do not remove topsoil or vegetation and written approval must be obtained before snow 

removal related to a federal action but outside of designated areas is undertaken.

 k. Prior to fill construction, the existing surface shall be sloped to avoid sharp banks and allow equipment 

operations. No fills shall be made with frozen or water saturated soils. Construction equipment shall be 

routed evenly over the entire width of the fill to obtain a thorough compaction.

 l. Construction holes left open over night shall be covered. Covers shall be secured in place and shall be 

strong enough to prevent livestock or wildlife from falling through and into a hole. 

m. Holder shall limit excavation to the areas of construction. No borrow areas for fill material will be 

permitted on the site. All off-site borrow areas must be approved in writing by the AO in advance of 

excavation. All waste material resulting from construction or use of the site by holder shall be removed 

from the site. All waste disposal sites on public land must be approved in writing by the AO in advance of 

use.

 n. Remove, and clearly segregate from all other spoil, all available topsoil from constructed locations, 

including areas of cut and fill, and stockpile at the site for use in reclamation on all other areas of surface 

disturbance (roads, pipelines, etc.).

 o. Drainage and runoff shall be diverted away from all new construction. All drainage structures shall 

simulate topographic contour lines, have a grade no greater than .5 - 1 percent, and shall release water onto 

undisturbed ground without causing additional and/or accelerated erosion. 

Operations: 

a. Except rights-of-way expressly authorizing a road after construction of the facility is completed, the holder 

shall not use the right-of-way as a road for purposes other than routine maintenance as determined 

necessary by the AO in consultation with the holder. 

b. The holder shall meet Federal, State, and local emission standards for air quality. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

c.	 The holder shall perform all operations in a good and workmanlike manner so as to ensure protection of 

the environment and the health and safety of the public. 

d.	 Holder shall maintain the right-of-way in a safe, usable condition, as directed by the AO. 

e.	 The holder must be prepared to provide BLM copies of applications for and approved federal, state, and 

local operating permits. 

f.	 If snow removal from the road is undertaken, equipment used for snow removal operations shall be 

equipped with shoes to keep the blade six-inches off the road surface. Holder shall take special 

precautions where the surface of the ground is uneven and at drainage crossings to ensure that equipment 

blades do not destroy vegetation. 

g.	 The holder shall permit free and unrestricted public access to and upon the right-of-way for all lawful 

purposes except for those specific areas designated as restricted by the authorized officer to protect the 

public, wildlife, livestock or facilities constructed within the right-of-way. 

Reclamation: 

a.	 The holder shall submit, in accordance with relevant EIS or AO determined dates, an annual report 

detailing the status of interim or final reclamation work and associated action for this ROW during the 

previous calendar year.

 b.	 The holder shall restore drainages, to the greatest extent possible, to the original bank configuration, 

stream bottom width, and channel gradient. Loose soil, fill, and culverts shall be removed from drainage 

channels as directed by the AO. 

c.	 The holder shall construct waterbars on all disturbed areas. Waterbars are to be constructed to: (1) 

simulate the imaginary contour lines of the slope (ideally with a grade of one or two percent); (2) drain 

away from the disturbed area; and (3) begin and end in vegetation or rock whenever possible. 

d.	 Any subsequent re-disturbance of interim reclamation shall be reclaimed within six (6) months by the 

same means described herein.

 e.	 Temporary fencing of the reclaimed well/facilities locations for the first two growing seasons after either 

interim or final seeding may be required to exclude livestock and wildlife and to help ensure better revegetation success. Similarly, off-road vehicle prevention measures shall be employed on reclaimed 

locations. 

f.	 All practicable measures will be utilized to minimize erosion and stabilize disturbed soils. Should the use 

or storage of hay, straw, or mulch be necessary, the holder is required to use certified weed-free hay, straw, 

and mulch on BLM lands. 

Pipelines: 

a.	 No surface disturbing activities shall take place on the subject right-of-way until the associated APD is 

approved. The holder will adhere to special stipulations in the Surface Use Program of the approved APD, 

relevant to any right-of-way facilities.

 b.	 Prior to any discharge, hydrostatic testing water will be tested and processed, if necessary, to ensure that 

the water meets local, State or Federal water quality standards. Prior to discharge of hydrostatic testing 

water from the pipeline, the holder shall design and install a suitable energy dissipater at the outlets, and 

design and install suitable channel protection structures necessary to ensure that there will be no erosion or 

scouring of natural channels within the affected watershed as a result of such discharge. The holder will be 

held responsible for any erosion or scouring resulting from such discharge. Sandbags, rock, or other 

materials or objects installed shall be removed from the site upon completion of hydrostatic testing.

 c.	 The holder shall design and construct adequate water-control structures in each drainage crossing to 

prevent excessive erosion along the pipeline and protect the pipeline from the natural erosion process 

within the drainage.

 d.	 If during any phase of the construction, operation, or termination of the pipeline or related facilities any oil 

or other pollutant should be discharged from the pipeline system, or from containers or vehicles impacting 

Federal lands, the control and total removal, disposal, and cleanup of such oil or other pollutant, wherever 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

found, shall be the responsibility of the holder, regardless of fault. Upon failure of holder to control, 

cleanup, or dispose of such discharge on or affecting Federal lands, or to repair all damages to Federal 

lands resulting there from, the AO may take such measures deemed necessary to control, clean up the 

discharge, and restore the area, including, where appropriate, the aquatic environment and fish and wildlife 

habitats, at the full expense of the holder. Such action by the AO shall not relieve the holder of any 

liability or responsibility. 

e. The holder is prohibited from discharging oil or other pollutants into or upon the navigable waters of the 

United States, adjoining shorelines, or the waters of the contiguous zone in violation of Section 311 of the 

Clean Water Act as amended, 33 U.S.C. 1321, and the regulations issued there under, or applicable laws of 

the State(s) of Wyoming and regulations issued there under. Holder shall give immediate notice of any 

such discharge to the AO and such other Federal and State officials as are required by law to be given such 

notice. 

f. All above-ground structures not subject to safety requirements shall be painted by the holder to blend with 

the natural color of the landscape. The paint used shall be a color which simulates "Standard 

Environmental Colors" designated by the Rocky Mountain Five-State Interagency Committee. The color 

selected for this pipeline is Shale Green (5Y 4/2). 

g. All cathodic protection facilities shall have approval from the Department of Environmental Quality 

(DEQ) UIC Division and have an approved Class V, Type 5F1 permit. 

Access Roads: 

a. No surface disturbing activities shall take place on the subject right-of-way until the associated APD is 

approved. The holder will adhere to special stipulations in the Surface Use Program of the approved APD, 

relevant to any right-of-way facilities.

 b. The holder shall furnish and install culverts of the gauge, materials, diameter(s), and length(s) indicated 

and approved by the authorized officer. Culverts shall be free of corrosion, dents, or other deleterious 

conditions. Culverts shall be placed on channel bottoms on firm, uniform beds which have been shaped to 

accept them and aligned to minimize erosion. Backfill shall be thoroughly compacted. No equipment 

shall be routed over a culvert until backfill depth is adequate to protect the culverts. 

c. Surfacing shall be designed to accommodate anticipated loading and traffic volumes and shall provide for 

future maintenance.

 d. All vehicles shall use only authorized travel routes and shall not use any other access route, such as twotrack roads, trails, and pipeline rights-of-way to the drill/well pad and any ancillary facilities. 

e. Two-track roads shall not be cut-off as a direct result of construction, maintenance, or reclamation of the 

well access road or associated well facilities. 

f. All access roads and drainage control structures, whether existing or newly-constructed, shall be both 

constructed to resource road standards and regularly maintained in a safe and usable condition as outlined 

in BLM Manual, Section 9113. A regular maintenance program may include, but is not limited to: 

blading, ditching, culvert installation, dust control, and gravel surfacing or other activities as specified by 

the AO. 

g. Prior to construction, road(s) shall be surveyed and staked with construction control stakes set 

continuously along the centerline at maximum 100-foot intervals (less where needed to be inter-visible) 

and at all tangent and curve control points, fence or utility crossings, and culverts. In addition to centerline 

stakes, slope stakes shall be placed at the top of the cut and the bottom of the fill for those portions of the 

road that are engineered. 

h. Before proposed road construction activities begin, the topsoil must be bladed to the side of the road and 

stockpiled. The topsoil stockpile shall be contoured so as to prevent water ponding or flow concentration. 

Once the barrow ditch and the cut slopes are constructed, cleared vegetative material and topsoil that is 

windrowed shall be spread back onto the cut/fill slopes of the road, removing any windrows or berms 

remaining at the edge of the road. 

i. The minimum travel-way width of the immediate access road will be 14 feet with turnouts at least 10 feet 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

in width. No structure will be allowed to narrow the road top. The inside slope will be 4:1. The bottom of 

the ditch will be a smooth V with no vertical cut in the bottom. The outside slope will be 2:1 or shallower. 

After the road is crowned and ditched with a .03 - .05 ft/ft crown the topsoil and windrowed vegetative 

material shall be pulled back down on the cut slope so there is no berm left at the top of the cut slope. 

Turnouts will be spaced at a maximum distance of 1000 feet and will be intervisible. If the access road 

crosses a floodplain, the ditch shall be flat-bottomed so as to provide material to raise the road. 

j.	 If soils along the access road route are dry during road construction, use, and/or maintenance, fresh water 

shall be applied to the road surface to facilitate soil compaction and minimize soil loss as a result of wind 

erosion. 

k.	 Construction and surfacing of the new access road shall be complete prior to moving drilling equipment 

onto the well pad and the presence of heavy vehicular traffic. Compact the top foot of sub-grade to a 95% 

maximum density as determined by AASHTO T-99. Surface with an appropriate grade of gravel to a 

minimum depth of four (compacted) inches.

 l.	 As directed by the authorizing officer, all road segments shall be winterized by providing a well-drained 

roadway by water baring, maintaining drainage, and any additional measures necessary to minimize 

erosion and other damage to the roadway or the surrounding public lands.

 m.	 Culverts shall have a minimum of 12" of fill or 1/2 the pipe diameter, whichever is greater, placed on top 

of the culvert, and shall be of length sufficient to allow at least 24" of culvert to extend from the fill slope 

face. The inlet and outlet shall be set on grade. No rocks shall be used in the bed material and no rocks 

greater than 2" in diameter will be immediately adjacent to the culvert. The entire length of pipe shall be 

bedded on native material before backfilling, which shall be completed using unfrozen material and rocks 

no larger than two inches in diameter; compact the backfill evenly in 6" lifts on both sides of the culvert. 

A permanent marker shall be installed at both ends of the culvert to help prevent traffic from damaging the 

culvert. Additional culverts will be placed in the new access road as the need arises or as directed by AO. 

n.	 Wing-ditches shall be staked and constructed at a slope of .5 to 1.0 percent down slope unless otherwise 

approved by the AO. In no case shall wing-ditches discharge adjacent to a channel bank.

 o.	 All drainage ditches and culverts shall be kept clear and free-flowing, and shall also be maintained in 

accordance with the original construction standards. 

Well Pads: 

a.	 No surface disturbing activities shall take place on the subject right-of-way until the associated APD is 

approved. The holder will adhere to special stipulations in the Surface Use Program of the approved APD, 

relevant to any right-of-way facilities.

 b.	 Construction control stakes shall be placed as necessary to ensure construction of the well pad, topsoil 

stockpile, spoil pile, and outer limits of the area to be disturbed in accordance with the specifications 

outlined in the APD. The holder shall assume full responsibility for protecting all stakes and offsetting any 

additional stakes or grades which may be necessary. 

c.	 All facilities on location that have the potential to leak/spill oil, glycol, methanol, produced water, 

condensate, or other fluids which may constitute a hazard to the environment, public health or safety 

(including, but not limited to, drain sumps, sludge holdings, and chemical containers), shall be within 

secondary containment, impervious to those fluids, exclusive of wildlife and livestock, with animal/bird 

escape capability, and able to contain a minimum of 110% of the volume of the largest storage vessel, 

respective to content, or 100% with at least one foot of freeboard, whichever is greater, so that any spill or 

leakage would not drain, infiltrate, or otherwise escape to ground water, surface water, or navigable waters 

before cleanup can be completed (within 72 hours). 

d.	 The holder shall comply with the construction practices and mitigating measures established by 33 CFR 

323.4, which sets forth the parameters of the "nationwide permit" required by Section 404 of the Clean 

Water Act. If the proposed action exceeds the parameters of the nationwide permit, the holder shall obtain 

an individual permit from the appropriate office of the Army Corps of Engineers and provide the AO with 

a copy of same. Failure to comply with this requirement shall be cause for suspension or termination of 

this right-of-way grant. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

e. Fencing shall be installed around produced water, oil, and condensate tank batteries in order to help 

maintain the integrity of the surrounding containment structure and to prevent livestock and wildlife from 

entering the area in case of a leak or spill. 

f. All open vent stack equipment shall be designed and constructed to prevent entry by birds and bats and to 

discourage perching.

 g. The holder is prohibited from discharging oil or other pollutants into or upon the navigable waters of the 

United States, adjoining shorelines, or the waters of the contiguous zone in violation of Section 311 of the 

Clean Water Act as amended, 33 U.S.C. 1321, and the regulations issued there under, or applicable laws of 

the State(s) of Wyoming and regulations issued there under. Holder shall give immediate notice of any 

such discharge to the AO and such other Federal and State officials as are required by law to be given such 

notice. 

h. All above-ground structures not subject to safety requirements shall be painted by the holder to blend with 

the natural color of the landscape. The paint used shall be a color which simulates "Standard 

Environmental Colors" designated by the Rocky Mountain Five-State Interagency Committee. The color 

selected for this pipeline is Shale Green (5Y 4/2). 

i. All roads and parking areas shall be constructed to provide drainage and minimize erosion. Culverts shall 

be installed if necessary to maintain drainage. All areas to be used for roads and parking shall be surfaced 

with gravel (before the drilling rig or other drilling equipment moves onto the pad). 

j. Emissions of particulate matter from well pad, road, and other facility construction, operation, and 

reclamation activities will be minimized by application of water or other dust suppressants. Dust inhibitors 

(surfacing materials, dust suppressants, and water) will be used as necessary on locations that present a 

fugitive dust problem. The use of chemical dust suppressants on public surface will require prior approval 

from the BLM Authorized Officer. 

k. If groundwater or permeable/porous subsoil or bedrock is encountered upon construction of the pad or pits, 

or upon drilling and completing shallow holes for surface conductor, rat/mouse holes, or water supply 

well, the holder must immediately notify the BLM Authorized Officer (AO) before proceeding.

 l. The holder shall comply with the Hazardous Materials Management Plan/Summary in the EIS, including 

requirements to transport, store, utilize, and dispose of hazardous substances. The holder shall maintain a 

hazardous substances release contingency plan that shall include, among other things, provision to notify 

the BLM Authorized Officer in the event of any release of hazardous substances associated with project 

operations.

 m. Interim reclamation of all disturbed areas not needed for production operations, including unnecessary 

access roads and pipeline right(s)-of-way, shall commence and be completed within six (6) months from 

date of reaching total depth or determination of inactivity. All fill and stockpiled soils shall be distributed 

on disturbed areas and the production pad shall be as small as possible to allow for safe and prudent 

production operations.

 n. Temporary fencing of the reclaimed well/facilities locations for the first two growing seasons after either 

interim or final seeding may be required to exclude livestock and wildlife and to help ensure better revegetation success. Similarly, off-road vehicle prevention measures shall be employed on reclaimed 

locations. 

o. Any topsoil to be stockpiled for longer than six (6) months shall be spread in layers of 2 feet maximum 

thickness, signed, and stabilized with a suitable cover crop (immediately post-construction and until 

successful) as approved of by the AO. 

p. Cathodic protection wells shall be drilled on the existing well pad, placed so as not to interfere with recontouring of cut and fill slopes during interim reclamation, designed and constructed to prevent 

commingling and contamination of water aquifers. The AO shall be notified of any water flows at surface 

and the problem will be resolved promptly. 

Pits: 

a. All oil and gas pits containing fracture/stimulation fluids are required to be lined with an impermeable (12 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-31
 

 

 

 

 

 

 

 

 

 

 

APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

mil minimum with a permeability less than or equal to 1 X 10-7 cm/sec) liner. The liner shall be physically 

and chemically-compatible with all substances which it may contact and shall be of sufficient strength and 

thickness to withstand normal installation and use, and installed so that it will not leak. The liner shall be 

installed over a smooth sub-grade, matting, or fill materials (e.g. sifted dirt, sand, or bentonite) free of 

pockets, loose rocks, and other objects that could damage the liner.

 b. The only fluids/waste materials which are authorized to go into reserve pits are RCRA-exempt exploration 

and production wastes. 

c. Any evidence of RCRA non-exempt wastes being put into the reserve pit may result in the BLM 

Authorized Officer requiring specific testing and closure requirements. 

d. Flaring of gas into the reserve or completion pits will not be allowed without prior approval from the AO. 

e. Pits are to be dried within six (6) months from the date that total depth was reached and prior to any 

backfilling. Trenching or squeezing is prohibited. Pits, once dry, shall be backfilled and compacted with a 

minimum cover of five (5) feet of soil, void of any topsoil, vegetation, large stones, rocks or foreign 

objects. The pit area shall be mounded to allow for settling and to promote positive surface drainage away 

from the pit. Before backfilling synthetically lined reserve pits, those liner portions remaining above the 

"mud line" shall be cut off as close to the top of the mud surface as possible and disposed of at an 

approved solid waste disposal facility. The pit bottom and remaining liner shall not be trenched, cut, 

punctured, or perforated. Installation and operation of any sprinklers, pumps, and related equipment shall 

ensure that water spray or mist does not drift outside of pit boundaries.

 f. All pits are required to maintain 2 feet of freeboard. If operations cause fluid levels in pits to rise above 

the required freeboard, immediate notification shall be provided to the AO with concurrent steps taken to 

cease the introduction of additional fluids, until alternative containment methods can be approved. 

g. For the protection of livestock and wildlife, all pits and open cellars shall be fenced on all sides, with 

corner bracing, immediately upon construction. Reserve, flare, completion, and production pits will be 

adequately fenced during and after drilling operations until pits are reclaimed so as to effectively keep out 

wildlife and livestock. Approved netting (mesh diameter no larger than one inch) is required over any pit 

that contains or is identified as containing hydrocarbons or hazardous substances (per RCRA 40 CFR Part 

261 or CERCLA Section 101(14) (E)).

 h. Only those hazardous wastes that qualify as exempt, under the Resource Conservation and Recovery Act 

(RCRA), Oil and Gas Exemption, may be disposed of in the reserve pit. Generally, oil or gas wastes are 

exempt if they 1) have been sent down hole and then returned to the surface during oil/gas operations 

involving exploration, development, or production, or 2) have been generated during the removal of 

produced water or other contaminants from the oil/gas production stream. The term hazardous waste, as 

referred to above, is defined as a listed (40 CFR 261.31-33) or characteristic (40 CFR 261.20-24) 

hazardous waste under RCRA. 

Water:

 a. If temporary surface lines are used to transport drilling water, lines shall be placed/removed when the 

ground surface is dry; no surface blading is allowed. The surface pipelines must be removed within 30 

days after completion (or determination of inactivity) of the well. 

b. All disposal and management of produced water must be in accordance with Onshore Oil and Gas Order 

No. 7.

 c. Any changes to water sources/supplies, fate of drilling/completion fluids, routes and means of fluid 

transportation, and location or method of produced water disposal must first have written approval from 

the AO. 

d. Within 90 days of initial production start-up the holder shall submit to the BLM authorized officer an 

analysis of the produced water. 

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APPENDIX C—BEST MANAGEMENT PRACTICES AND CONDITIONS OF APPROVAL 

IN WITNESS WHEREOF, The undersigned agrees to the terms and conditions of this right-of-way 

grant or permit. 

(Signature of Holder) 

(Title) 

(Signature of BLM Authorized 

Officer) 

Field Manager, Rawlins Field Office 

(Title) 

(Date) (Effective Date of Grant) 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 C-33 
APPENDIX D: PALEONTOLOGICAL RESOURCES PROGRAM 

 GUIDANCE 

Table of Contents 

Instruction Memorandum No. 2008-009.................................................................................... 1
 

Attachment 1. ............................................................................................................................................ 3
 

Potential Fossil Yield Classification (PFYC) System ............................................................................... 3
 

Attachment 2. ............................................................................................................................................ 7
 

Guidance for Implementing the Potential Fossil Yield Classification (PFYC) System............................ 7
 

Introduction........................................................................................................................................... 7
 

Uses....................................................................................................................................................... 7
 

Assignment of Classes .......................................................................................................................... 8
 

Application............................................................................................................................................ 8
 

Mitigation Needs Assessment ............................................................................................................... 9
 

Further Information ............................................................................................................................. 10
 

Instruction Memorandum No. 2009-011.................................................................................. 11
 

Attachment 1. .......................................................................................................................................... 13
 

Guidelines for Assessment and Mitigation of Potential Impacts to Paleontological Resources ............. 13
 

Introduction......................................................................................................................................... 13
 

Assessment of Potential Impacts to Paleontological Resources ......................................................... 13
 

II. Procedures for Conducting a Paleontological Field Survey .................................................... 17
 

III. Determination of Further Mitigation Requirements ................................................................ 20
 

IV. Procedures for Field Monitoring ............................................................................................. 21
 

V. Final Project Report................................................................................................................. 24
 

VI. Completion of Mitigation Responsibility ............................................................................... 24
 

VII. Collections Resulting from Assessment and Mitigation......................................................... 24
 

VIII. Resource Management Updates .............................................................................................. 25
 

Appendix A to Attachment 1 – Definitions ........................................................................................ 26
 

Attachment 2. .......................................................................................................................................... 30
 

Paleontological Resources Assessment Flowchart ................................................................................. 30
 

Paleontological Actions .......................................................................................................................... 31
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 D-i 
 

APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

INSTRUCTION MEMORANDUM NO. 2008-009 

UNITED STATES DEPARTMENT OF THE INTERIOR 

BUREAU OF LAND MANAGEMENT
 

Washington, D.C. 20240
 

October 15, 2007
 

In Reply Refer To: 

1610, 8270 (240) P 

EMS TRANSMISSION 10/18/2007 

Expires: 09/30/2009 

To:	 All State Directors 

From: Assistant Director, Renewable Resources and Planning 

Subject:	 Potential Fossil Yield Classification (PFYC) System for Paleontological Resources on

 Public Lands 

Program Areas: Paleontological Resources Management, Resource Management Planning, Lands and 

Realty Management, Minerals Management, Range 

Purpose: This Instruction Memorandum (IM) transmits the Bureau of Land Management (BLM) 

classification system for paleontological resources on public lands. The classification system is based on 

the potential for the occurrence of significant paleontological resources in a geologic unit, and the 

associated risk for impacts to the resource based on Federal management actions. Copies of the 

classification system and implementation guidance are attached. 

Policy/Action: The Potential Fossil Yield Classification (PFYC) system will be used to classify 

paleontological resource potential on public lands in order to assess possible resource impacts and 

mitigation needs for Federal actions involving surface disturbance, land tenure adjustments, and land-use 

planning. Implementation of the PFYC system will not mandate changes to existing land use plans, 

project plans, or other completed efforts. Integration into plans presently being developed is 

discretionary. All efforts subsequent to issuance of this IM should incorporate the PFYC system. This 

system will replace the current Condition Classification in the Handbook (H-8270-1) for Paleontological 

Resource Management. 

Timeframe: This guidance is effective immediately for all BLM offices. 

Background: This classification system for paleontological resources is intended to provide a more 

uniform tool to assess potential occurrences of paleontological resources and evaluate possible impacts. It 

uses geologic units as base data, which is more readily available to all users. It is intended to be applied in 

broad approach for planning efforts, and as an intermediate step in evaluating specific projects. This is 

part of a larger effort to update the Handbook H-8270-1 (General Procedural Guidance for 

Paleontological Resource Management) Chapter III (Assessment & Mitigation) and Chapter II.A.2 and 

will be incorporated into that Handbook update. 

Impact on Budget: Costs for the initial classification of geologic units for those States that have not 

already determined the classification will be borne by each Office. Implementation of the PFYC system 

will have no additional costs. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Manual/Handbook Affected: Supersedes H-8270-1 (General Procedural Guidance for Paleontological 

Resource Management) Chapter II.A.2. 

Coordination: The classification system is the product of the BLM’s regional paleontologists, other 

BLM employees, and outside reviewers. This system is very similar to the Forest Service’s Fossil Yield 

Potential Classification and will enable closer coordination of paleontological resource management 

between the agencies. 

Contact: For questions regarding application of this policy and guidance, please contact Lucia Kuizon, 

National Paleontologist, at (202) 452-5107 or lkuizon@blm.gov. 

Signed by: Todd S. Chirstensen Authenticated by: Robert M. Williams 

Acting, Deputy Assistant Director Division of IRM Governance 

Renewable Resources and Planning 

2 Attachments: 

 1 – The Potential Fossil Yield Classification (PFYC) System (4 pp) 

 2 – Guidance for Implementing the PFYC System (5 pp) 

D-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Attachment 1. 

Potential Fossil Yield Classification (PFYC) System
 

Occurrences of paleontological resources are closely tied to the geologic units (i.e., formations, members, 

or beds) that contain them. The probability for finding paleontological resources can be broadly predicted 

from the geologic units present at or near the surface. Therefore, geologic mapping can be used for 

assessing the potential for the occurrence of paleontological resources. 

Using the Potential Fossil Yield Classification (PFYC) system, geologic units are classified based on the 

relative abundance of vertebrate fossils or scientifically significant invertebrate or plant fossils and their 

sensitivity to adverse impacts, with a higher class number indicating a higher potential. This classification 

is applied to the geologic formation, member, or other distinguishable unit, preferably at the most detailed 

mappable level. It is not intended to be applied to specific paleontological localities or small areas within 

units. Although significant localities may occasionally occur in a geologic unit, a few widely scattered 

important fossils or localities do not necessarily indicate a higher class; instead, the relative abundance of 

significant localities is intended to be the major determinant for the class assignment. 

The PFYC system is meant to provide baseline guidance for predicting, assessing, and mitigating 

paleontological resources. The classification should be considered at an intermediate point in the analysis, 

and should be used to assist in determining the need for further mitigation assessment or actions. 

The descriptions for the classes below are written to serve as guidelines rather than as strict definitions. 

Knowledge of the geology and the paleontological potential for individual units or preservational 

conditions should be considered when determining the appropriate class assignment. Assignments are 

best made by collaboration between land managers and knowledgeable researchers. 

Class 1 – Very Low. Geologic units that are not likely to contain recognizable fossil remains. 

 Units that are igneous or metamorphic, excluding reworked volcanic ash units. 

 Units that are Precambrian in age or older. 

(1) Management concern for paleontological resources in Class 1 units is usually negligible or not 

applicable. 

(2) Assessment or mitigation is usually unnecessary except in very rare or isolated circumstances. 

The probability for impacting any fossils is negligible. Assessment or mitigation of paleontological 

resources is usually unnecessary. The occurrence of significant fossils is non-existent or extremely rare. 

Class 2 – Low. Sedimentary geologic units that are not likely to contain vertebrate fossils or scientifically 

significant nonvertebrate fossils. 

 Vertebrate or significant invertebrate or plant fossils not present or very rare. 

 Units that are generally younger than 10,000 years before present. 

 Recent aeolian deposits. 

 Sediments that exhibit significant physical and chemical changes (i.e., diagenetic alteration). 

(1) Management concern for paleontological resources is generally low. 

(2) Assessment or mitigation is usually unnecessary except in rare or isolated circumstances. 

The probability for impacting vertebrate fossils or scientifically significant invertebrate or plant fossils is 

low. Assessment or mitigation of paleontological resources is not likely to be necessary. Localities 

containing important resources may exist, but would be rare and would not influence the classification. 

These important localities would be managed on a case-by-case basis. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 D-3 
 

APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Class 3 – Moderate or Unknown. Fossiliferous sedimentary geologic units where fossil content varies in 

significance, abundance, and predictable occurrence; or sedimentary units of unknown fossil potential. 

 Often marine in origin with sporadic known occurrences of vertebrate fossils. 

 Vertebrate fossils and scientifically significant invertebrate or plant fossils known to occur 

intermittently; predictability known to be low. 

(or) 

 Poorly studied and/or poorly documented. Potential yield cannot be assigned without ground 

reconnaissance. 

Class 3a – Moderate Potential. Units are known to contain vertebrate fossils or scientifically 

significant nonvertebrate fossils, but these occurrences are widely scattered. Common 

invertebrate or plant fossils may be found in the area, and opportunities may exist for hobby 

collecting. The potential for a project to be sited on or impact a significant fossil locality is low, 

but is somewhat higher for common fossils. 

Class 3b – Unknown Potential. Units exhibit geologic features and preservational conditions 

that suggest significant fossils could be present, but little information about the paleontological 

resources of the unit or the area is known. This may indicate the unit or area is poorly studied, 

and field surveys may uncover significant finds. The units in this Class may eventually be placed 

in another Class when sufficient survey and research is performed. The unknown potential of the 

units in this Class should be carefully considered when developing any mitigation or management 

actions. 

(1) Management concern for paleontological resources is moderate; or cannot be determined from 

existing data. 

(2) Surface-disturbing activities may require field assessment to determine appropriate course of 

action. 

This classification includes a broad range of paleontological potential. It includes geologic units of 

unknown potential, as well as units of moderate or infrequent occurrence of significant fossils. 

Management considerations cover a broad range of options as well, and could include pre-disturbance 

surveys, monitoring, or avoidance. Surface-disturbing activities will require sufficient assessment to 

determine whether significant paleontological resources occur in the area of a proposed action, and 

whether the action could affect the paleontological resources. These units may contain areas that would be 

appropriate to designate as hobby collection areas due to the higher occurrence of common fossils and a 

lower concern about affecting significant paleontological resources. 

Class 4 – High. Geologic units containing a high occurrence of significant fossils. Vertebrate fossils or 

scientifically significant invertebrate or plant fossils are known to occur and have been documented, but 

may vary in occurrence and predictability. Surface disturbing activities may adversely affect 

paleontological resources in many cases. 

Class 4a – Unit is exposed with little or no soil or vegetative cover. Outcrop areas are extensive 

with exposed bedrock areas often larger than two acres. Paleontological resources may be 

susceptible to adverse impacts from surface disturbing actions. Illegal collecting activities may 

impact some areas. 

Class 4b – These are areas underlain by geologic units with high potential but have lowered risks 

of human-caused adverse impacts and/or lowered risk of natural degradation due to moderating 

circumstances. The bedrock unit has high potential, but a protective layer of soil, thin alluvial 

material, or other conditions may lessen or prevent potential impacts to the bedrock resulting 

from the activity. 

D-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

	 Extensive soil or vegetative cover; bedrock exposures are limited or not expected to be 

impacted. 

 Areas of exposed outcrop are smaller than two contiguous acres. 

 Outcrops form cliffs of sufficient height and slope so that impacts are minimized by 

topographic conditions. 

 Other characteristics are present that lower the vulnerability of both known and unidentified 

paleontological resources. 

(1) Management concern for paleontological resources in Class 4 is moderate to high, depending on 

the proposed action. 

(2) A field survey by a qualified paleontologist is often needed to assess local conditions. 

(3) Management prescriptions for resource preservation and conservation through controlled access 

or special management designation should be considered. 

(4) Class 4 and Class 5 units may be combined as Class 5 for broad applications, such as planning 

efforts or preliminary assessments, when geologic mapping at an appropriate scale is not 

available. Resource assessment, mitigation, and other management considerations are similar at 

this level of analysis, and impacts and alternatives can be addressed at a level appropriate to the 

application. 

The probability for impacting significant paleontological resources is moderate to high, and is dependent 

on the proposed action. Mitigation considerations must include assessment of the disturbance, such as 

removal or penetration of protective surface alluvium or soils, potential for future accelerated erosion, or 

increased ease of access resulting in greater looting potential. If impacts to significant fossils can be 

anticipated, on-the-ground surveys prior to authorizing the surface disturbing action will usually be 

necessary. On-site monitoring or spot-checking may be necessary during construction activities. 

Class 5 – Very High. Highly fossiliferous geologic units that consistently and predictably produce 

vertebrate fossils or scientifically significant invertebrate or plant fossils, and that are at risk of humancaused adverse impacts or natural degradation. 

Class 5a – Unit is exposed with little or no soil or vegetative cover. Outcrop areas are extensive 

with exposed bedrock areas often larger than two contiguous acres. Paleontological resources are 

highly susceptible to adverse impacts from surface disturbing actions. Unit is frequently the focus 

of illegal collecting activities. 

Class 5b – These are areas underlain by geologic units with very high potential but have lowered 

risks of human-caused adverse impacts and/or lowered risk of natural degradation due to 

moderating circumstances. The bedrock unit has very high potential, but a protective layer of soil, 

thin alluvial material, or other conditions may lessen or prevent potential impacts to the bedrock 

resulting from the activity. 

 Extensive soil or vegetative cover; bedrock exposures are limited or not expected to be 

impacted. 

 Areas of exposed outcrop are smaller than two contiguous acres. 

 Outcrops form cliffs of sufficient height and slope so that impacts are minimized by 

topographic conditions. 

 Other characteristics are present that lower the vulnerability of both known and unidentified 

paleontological resources. 

(1) Management concern for paleontological resources in Class 5 areas is high to very high. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

(2) A field survey by a qualified paleontologist is usually necessary prior to surface disturbing 

activities or land tenure adjustments. Mitigation will often be necessary before and/or during 

these actions. 

(3) Official designation of areas of avoidance, special interest, and concern may be appropriate. 

The probability for impacting significant fossils is high. Vertebrate fossils or scientifically significant 

invertebrate fossils are known or can reasonably be expected to occur in the impacted area. On-theground surveys prior to authorizing any surface-disturbing activities will usually be necessary. Onsite 

monitoring may be necessary during construction activities. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Attachment 2. 

Guidance for Implementing the Potential Fossil Yield Classification (PFYC) System
 

Introduction 

The Potential Fossil Yield Classification (PFYC) system will aid in assessing the potential for discovery 

of significant paleontological resources or the impact of surface disturbing activities to these resources. 

It is intended to assist in determining proper mitigation approaches for surface disturbing activities, 

disposal or acquisition actions, recreation possibilities or limitations, and other BLM-approved activities. 

It will provide consistent information for input and analysis during planning efforts. The PFYC system 

can also highlight the areas most likely to be a focus of paleontological research efforts or illegal 

collecting. It is hoped that this system will allow BLM to direct management efforts toward potentially 

significant areas and reduce efforts in areas of lower potential. 

This classification system was originally developed by the Forest Service’s Paleontology Center of 

Excellence and the Region 2 (FS) Paleontology Initiative in 1996. Modifications were made by the 

BLM’s Paleontological Resources staff in subsequent years. 

Paleontological resources are closely associated with the geologic rock units containing them; that is, 

fossils are found more frequently in some rock units than others. The management of paleontological 

resources can thus be tied to the geologic units present at or near the ground surface, with greater 

management emphasis aimed at higher potential geologic units. 

Uses 

This PFYC system is utilized for land use planning efforts and for the preliminary assessment of potential 

impacts and proper mitigation needs for specific projects. It is intended to provide a tool to assess 

potential occurrences of significant paleontological resources. It is meant to be applied in broad approach 

for planning efforts, and as an intermediate step in evaluating specific projects. 

There are five Classes with Class 1 being Very Low Potential and Class 5 being Very High Potential. 

Although granite, lava beds, and other igneous or metamorphic rock types are usually considered to be 

void of any fossils, outcrops of these rocks may have fissure fillings, cave-like structures, sinkholes, and 

other features that may preserve significant paleontological resources or information, so the potential is 

not zero; therefore Class 1 is applied to these rock types usually considered not to contain fossil resources. 

It is intended that this system replace the current Condition Classification in the Handbook (H-8270-1), 

for Paleontological Resource Management. In general, the following is a comparison of the Condition 

Classification rankings to the new PFYC Classes: 

Classes: Condition (from H-8270-1) PFYC Class (this Instruction Memorandum) 

Condition 1 – Areas known to contain vertebrate fossils 

or noteworthy occurrences of invertebrate or plant 

fossils. (Note: this refers to known localities or groups 

of localities) 

PFYC Class 4 (High) or Class 5 (Very High), based on 

geologic unit. 

Condition 2 – Areas with exposures of geological units 

or settings that have high potential to contain 

vertebrate fossils or noteworthy occurrences of 

invertebrate or plant fossils. 

PFYC Class 3 (Moderate), Class 4 (High), or Class 5 

(Very High), based on geologic unit. 

Condition 3 – Areas that are very unlikely to produce 

vertebrate fossils or noteworthy occurrences of 

invertebrate or plant fossils. 

PFYC Class 1 (Very Low) or Class 2 (Low). 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Assignment of Classes 

A separate class ranking is assigned to each recognized geologic formation or member present at the 

surface. Deposits of young alluvium (post-Pleistocene) or thick soils can often be ignored. However, 

geologic mapping may not separate the older Pleistocene alluvium which, may contain significant 

vertebrate fossils, and thus these units need to be carefully considered. Available geologic mapping, 

depending on map scale, may combine multiple formations or units. In these cases, the assigned 

classification should use the highest class of those included units. For ease of application, the 

classifications should be integrated into a Geographic Information System (GIS) based geologic map. 

The classification is initially determined by the Regional Paleontologist; the State Office Paleontology 

Lead in collaboration with the Regional Paleontologist; or by knowledgeable individuals from a 

paleontology museum, university paleontology department, or consulting firm working under a formal 

agreement. Several States have already completed an initial classification and are incorporating the 

system into new planning and mitigation efforts. 

To maintain consistency in planning efforts, mitigation requirements, and other management approaches, 

the classification should be applied to each formation on a state-wide basis, and even across State 

boundaries. But in some situations, geologic characteristics within formations may change across the 

State or region and may alter the potential for fossil occurrence. These differences may be a characteristic 

of the formation, be variable in occurrence, and unmappable at a workable scale; or may indicate a 

regional gradient, where a formation is highly fossiliferous in one portion of the State, but has lowered 

potential in another area. A variable occurrence in potential may be included in the general information 

about the formation. A regional gradient can be addressed by assigning a different class for separate areas. 

Multiple class assignments for an individual formation should be applied in consultation with the State 

Office to maintain consistency across Field Office boundaries. 

Over time, additional information may be acquired or developed that may suggest that a change in the 

class assignment is appropriate, especially from the Unknown Class (3b) to a higher or lower class. The 

classification should reflect the most current information, and recent research or discoveries may indicate 

a change is warranted. However, any changes should be measured against existing applications or use of 

the current classification, such as usage in Resource Management Plans (RMPs) or other planning or 

management documents. 

Application 

In planning documents and other general applications, these classes allow for uniform discussion of the 

paleontologic resource, potential adverse impacts, and management approaches. Assessment of general 

conditions, such as acres or percentages of each class, or spatial identification of important areas can be 

determined and presented in simple manner. Identification of areas of potential concern with other 

resources can be identified using GIS mapping or explained in the text body in simple fashion. 

The PFYC classes may also be utilized to assess the possibility of adverse or beneficial impacts from land 

tenure adjustment (disposal or acquisition) proposals prior to on-the-ground surveys. 

A primary purpose of the PFYC is to assess the possible impacts from surface disturbing activities and 

help determine the need for pre-disturbance surveys and monitoring during construction. This assessment 

should be an intermediate step in the analysis process; and local conditions such as amount of exposed 

bedrock should be considered when final mitigation needs are determined. The determination should also 

be supplemented by occurrences of known fossil localities and local geologic and topographic knowledge. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Mitigation Needs Assessment 

Impacts of most surface-disturbing activities, and the need for mitigation efforts, are addressed by the 

local Field Office. Some larger actions, such as major pipeline projects, may be handled by the State 

Office, or even as multi-State projects. In all these cases, the assessment of impacts to paleontological 

resources and need for mitigation can be addressed in similar fashion through a progression of steps. The 

following outlines the general steps used to apply the PFYC system to this mitigation process. 

1. Identify the Proposed Action and affected area. Consider the area directly impacted by the action, 

as well as areas that may be impacted by vehicle drive ways, equipment parking, storage areas, and 

increased access. Also consider the depth of disturbance to determine possible subsurface impacts. 

2. Identify the potential impacts to paleontological resources. Determine the geologic units that may 

be impacted and the associated PFYC classes, and consult other sources of information about known 

localities or paleontological research that may have been done previously. 

Based on the PFYC class and any additional resource information, determine the probability of 

impacting significant paleontological resources. If known localities are in the area of possible impact, 

determine if those localities can be avoided by altering the proposed action, such as repositioning a 

well pad location or rerouting a pipeline around a locality. 

3. Determine the need for field survey or other mitigation efforts. On-the-ground field surveys, onsite monitoring, spot-checking at key times during construction, or locality avoidance are all possible 

mitigation approaches to lessen adverse impacts. 

	 If the PFYC class for the impacted area is Class 1 or 2, and there are no known localities within 

the area, no further assessment is typically needed. 

	 If a Class 3a (Moderate Potential) unit underlies the area, the local geologic conditions should be 

considered, as well as any known localities in the region. It may be necessary to consult with the 

Regional Paleontologist or other qualified paleontologist to assess the local conditions. 

	 If a Class 3b (Unknown Potential) unit underlies the area, it may be appropriate to require an onsite preliminary assessment by a qualified paleontologist. 

	 If the area is a Class 4b (buried bedrock with High Potential) or Class 5b (buried bedrock with 

Very High Potential), an assessment of the possible impacts to bedrock units must be made. If the 

proposed action will not penetrate the protective soil or alluvial layer, a pre-work survey or 

monitoring during the activity may not be necessary. If the potential exists to remove the 

protective layer and impact the bedrock unit below, it may be prudent to require a pre-work field 

survey and/or on-site monitoring during disturbance or spot-checks at key times. Because the 

bedrock unit is typically buried for much of the area in question, a pre-work survey may not 

always be necessary, as the fossil material may not be visible. However, it may then be more 

important to have an on-site monitor during disturbance or spot-checks at key times. 

	 If it is a Class 4a (exposed bedrock with High Potential) or Class 5a (exposed bedrock with Very 

High Potential) area, it will be necessary in most (Class 4a) or almost all (Class 5a) situations to 

require a pre-activity field survey of the areas directly and indirectly impacted. 

	 Larger projects may impact multiple geologic units with differing PFYC Classes. In those cases, 

field survey and monitoring may be applied at differing levels. For example, surveys may be 

appropriate only on the Class 4 and 5 formations and not the Class 2 formations along a pipeline 

project. Careful mapping and detailed field notes should reflect the differing survey/monitoring 

intensities, and should be included in the consultant’s report to BLM. 

4. Conduct Pre-work Field Survey. Field surveys are almost always needed for Class 4 and 5 units, 

especially exposed bedrock areas (Class 4a and 5a). Class 3 units may or may not require a survey. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Local conditions, such as vegetated areas or pockets of bedrock exposure, may affect the need and 

intensity of field surveys. 

The consultant is required to submit a report of findings after completion of the field survey. In 

addition to standard reporting information, the report should contain the consultants’ 

recommendations for further mitigation, and this recommendation should be considered when 

determining the need for and type of on-site monitoring or locality avoidance. 

5. Monitor during disturbance activities. Those areas that have been determined to have a Very High 

potential (Class 5) for adverse impacts should typically be monitored at all times when surfacedisturbing activities are occurring. If the area has a High potential (Class 4), it may be appropriate to 

examine the exposed unit, including the spoil or storage piles, only at key times. These times are 

dependent on the activity, but typically are: when bedrock is initially exposed, occasionally during 

active excavation, and when the maximum exposure is reached and before backfilling has begun. This 

monitoring and spot-checking must be performed by a permitted paleontologist or their BLMapproved representative. The monitor has the authority to briefly pause any activity to inspect a 

possible find. These pauses are intended to allow for identification of possible fossil resources and 

should only last a few minutes to a couple hours. 

6. Evaluate significant finds. If significant paleontological resources are discovered during surface 

disturbing actions or at any other time, the proponent or any of his agents must: (a) stop work 

immediately at that site; (b) contact the appropriate BLM representative, typically the project 

inspector or Authorized Officer, as soon as possible; and (c) make every effort to protect the site from 

further impacts, including looting, erosion, or other human or natural damage. The BLM or 

designated paleontologist will evaluate the discovery and take action to protect or remove the 

resource within 10 working days. Work may not resume at that location until approved by the official 

BLM representative. In some cases, such as recovery of a dinosaur, further activity at that site may be 

delayed until the discovered fossils are recovered, or until the project is modified to avoid impacting 

the find. Because of the potential for lengthy delays, the BLM should assure that the project 

proponent understands this possibility prior to approval to begin work. 

These steps are included here to provide general guidance, and it may be appropriate to modify or skip 

them for various situations. However, a brief discussion of the background and reason for modification 

should be placed in the project file. 

For all surface-disturbing activities occurring within Class 3 or higher units, a stipulation should be 

included in the permitting document. 

Further Information 

Detailed information on the geologic units and paleontological resources within a State can often be 

obtained from State geological surveys, geological or paleontological museums, geology departments at 

universities or colleges, paleontological permittees or other researchers or within the BLM from Regional 

Paleontologists or knowledgeable Geologists. 

Scientific publications, such as professional journals or State geological survey reports, often contain 

general and detailed information about paleontological and geological resources relevant to fossil 

potential and occurrences for specific areas. Current and past paleontological permittee reports usually 

include precise locality data and maps, and often contain discussions of findings and their significance. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

INSTRUCTION MEMORANDUM NO. 2009-011 

UNITED STATES DEPARTMENT OF THE INTERIOR 

BUREAU OF LAND MANAGEMENT
 

WASHINGTON, D.C. 20240
 

October 10, 2008
 

In Reply Refer To: 

8270, 1790 (240) P 

EMS TRANSMISSION 10/29/2008 

Expires: 09/30/2010 

To: All State Directors 

From: Assistant Director, Renewable Resources and Planning 

Subject: Assessment and Mitigation of Potential Impacts to Paleontological Resources 

Program Areas: Paleontological Resources Management, Environmental Assessment 

Purpose: This Instruction Memorandum (IM) provides guidelines for assessing potential impacts to 

paleontological resources in order to determine mitigation steps for federal actions on public lands under 

the Federal Land Policy and Management Act (FLPMA) and the National Environmental Policy Act 

(NEPA). These guidelines also apply where a federal action impacts split-estate lands. In addition, this 

IM provides field survey and monitoring procedures to help minimize impacts to paleontological 

resources from federal actions in the case where it is determined that significant paleontological resources 

will be adversely affected by a federal action. 

Policy/Action: It is the policy of the BLM that potential impacts from federal actions on public lands, 

including land tenure adjustments, be identified and assessed, and proper mitigation actions be 

implemented when necessary to protect scientifically significant paleontological resources. This policy 

also applies to federal actions impacting split-estate lands and is subject to the right of landowners to 

preclude evaluation and mitigation of paleontological resources on their land. Paleontological resources 

removed from public lands require a Paleontological Resources Use permit for collection. Significant 

paleontological resources collected from public lands are federal property and must be deposited in an 

approved repository. Paleontological resources collected from split-estate lands are the property of the 

surface-estate owner, and their disposition will be in accordance with the surface agreement between the 

landowner and the permittee. 

Timeframe: This guidance is effective immediately for all BLM offices. 

Background: Surface disturbing activities may cause direct adverse impacts to paleontological resources 

through the damage or destruction of fossils; or loss of valuable scientific information by the disturbance 

of the stratigraphic context in which fossils are found. Indirect adverse impacts may be created by 

increased accessibility to important paleontological resources leading to looting or vandalism. Land 

tenure adjustments may result in the loss of significant paleontological resources to the public if 

paleontological resources pass from public ownership. Generally, the project proponent is responsible for 

the cost of implementing mitigation measures including the costs of investigation, salvage and curation of 

paleontological resources. 

This IM together with the Potential Fossil Yield Classification system (PFYC; see IM 2008-009) will 

provide guidance for the assessment of potential impacts to paleontological resources, field survey and 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

monitoring procedures, and recommended mitigation measures that will better protect paleontological 

resources impacted by federal actions. This guidance expands and clarifies the guidance in the Handbook 

H-8270-1 (General Procedural Guidance for Paleontological Resource Management) Chapter III 

(Assessment & Mitigation) and will be incorporated into the next Handbook revision. 

Impact on Budget: Costs are minimal for implementation of this guidance since mitigation of 

paleontological resources is already part of any approval of surface-disturbing actions on public lands. 

Manual/Handbook Affected: Supersedes Handbook H-8270-1 (General Procedural Guidance for 

Paleontological Resource Management) Chapter III.B. 

Coordination: Washington Office Division of Cultural and Paleontological Resources and Tribal 

Consultation. 

Contact: For questions regarding application of this policy and guidance, please contact Lucia Kuizon, 

National Paleontologist, at (202) 452-5107 or lkuizon@blm.gov. 

Signed by: Authenticated by: 

Edwin L. Roberson Robert M. Williams 

Assistant Director Division of IRM Governance,WO-560 

Renewable Resources and Planning 

2 Attachments: 

 1- Guidelines for Assessment and Mitigation of Potential Impacts to Paleontological Resources 

 2- Paleontological Resources Assessment Flowchart 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Attachment 1. 

Guidelines for Assessment and Mitigation of 

Potential Impacts to Paleontological Resources 

Introduction 

Surface disturbing federal actions on public and split-estate lands may cause direct adverse impacts 

to paleontological resources through the damage or destruction of fossils or the disturbance of the 

stratigraphic context in which they are located. Indirect adverse impacts may be created from 

increased accessibility to fossils leading to looting or vandalism activities. Land tenure adjustments 

may result in the loss of significant paleontological resources to the public if fossils pass from public 

ownership. 

Under the Federal Land Policy and Management Act (FLPMA) and the National Environmental 

Policy Act (NEPA), federal actions and land tenure adjustments that may impact or result in a loss of 

paleontological resources on public or split-estate lands are evaluated, and necessary mitigation is 

identified. 

Assessment of Potential Impacts to Paleontological Resources 

The following sections outline general steps designed to assist in the analysis and assessment of 

possible impacts to paleontological resources from proposed actions. These sections are sequential in 

order and provide for termination of the assessment at various stages if the analysis indicates no 

impacts are likely to occur. 

A. Scoping. Field Offices must assess all proposed federal actions to identify possible effects to 

significant paleontological resources (see Appendix A for definition) that are potentially 

recoverable and are likely to be within the zone of expected surface disturbance or relatively 

close to the surface. The direct effects of all surface activities and the indirect effects of 

increased public access and land tenure adjustments must be considered in any paleontological 

assessment. The assessment will determine whether further analysis will be necessary. The 

Paleontology Program Coordinator (Paleontology Coordinator – see Appendix A for definition) 

has primary responsibility for the scoping process for projects within the Field Office area, but 

the Paleontology Program Lead (Paleontology Lead – see Appendix A for definition) may be 

responsible for projects that span multiple Field or District Offices, and can support the 

Paleontology Coordinator as requested. 

1.	 Surface only activities – If the proposed project will not disturb potentially fossil-yielding 

bedrock or alluvium, no additional work is necessary. The project file should be documented 

as appropriate. Examples of such projects include weed spraying, mechanical brush 

treatment, geophysical exploration, or surface disturbing activities such as road construction 

when the fossil resource is expected to be buried well below project compression or 

excavation depth or when surface fossil resources would be left undamaged. 

2.	 Land Tenure Adjustments – If parcels are identified to pass from public ownership in a 

proposed land tenure adjustment action but contain no potential for recoverable, significant 

paleontological resources, no additional work is necessary. The project file should be 

documented as appropriate, and conclusions addressed in the environmental document. This 

situation may arise, for example, in areas consisting only of granitic bedrock where 

paleontological resources would not normally occur. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

3.	 Young alluvial deposits or deep soils may cover and obscure sedimentary bedrock, and any 

fossils that may occur in that bedrock would be unidentifiable or irretrievable prior to 

disturbance actions. In most of these cases, the fossil resources cannot be quantified, but the 

potential for impacting paleontological resources should be mentioned in the evaluation of 

the proposal, i.e., the planned disturbance will pass through the soil layer and impact a 

bedrock unit which is known to contain significant fossils elsewhere. 

If the initial scoping identifies the possibility for adversely affecting significant 

paleontological resources, further analysis is necessary. If there will be no impact or potential 

impact based on the action or the fossil resource may be impacted, but is too deep to be 

recovered, e.g., deep well bore passing through a fossil formation, the project file must be 

documented, and no additional assessment is necessary. 

B. Analysis of Existing Data. If scoping suggests the possibility of disturbing fossil-yielding 

bedrock or alluvium that is near to the surface and that may contain significant paleontological 

resources that are potentially recoverable, more in-depth analysis is necessary. Geologic mapping 

reflecting the Potential Fossil Yield Classification (PFYC) should be consulted, along with any other 

easily accessible information, such as GIS-based locality data, other known paleontological locality 

information, and existing paleontological reports for the area, aerial photos, or soils maps. 

1.	 Potential Fossil Yield Classification (PFYC) – This is a system for categorizing the 

probability of geologic units to contain scientifically significant paleontological resources or 

noteworthy fossil occurrences. It has five levels or Classes, with Class 1 applied to geologic 

units that are not likely to contain significant fossils through Class 5 for geologic formations 

that have a high potential to yield scientifically significant fossils on a regular basis (see IM 

No. 2008-009). This classification does not reflect rare or isolated occurrences of significant 

fossils or individual localities, only the relative occurrence on a formation- or member-wide 

basis. Any rare occurrences may require additional assessment and mitigation if they fall 

within the area of anticipated impacts. 

2.	 If the results of the preliminary analysis determine that the proposed project will only affect 

geologic units not likely to contain significant fossils or that have a very low or low potential 

for significant fossils (PFYC Class 1or 2), and no scientifically important localities are 

known to occur in the area, the project file should be documented, and no additional 

paleontology assessment is necessary. 

3.	 The results of an analysis of a proposed project may indicate the potential to disturb PFYC 

Class 3, 4, or 5 formations or potentially fossil-bearing alluvium, or known significant 

localities, which may then suggest the need for field surveys and/or other mitigation 

measures. The results may also identify areas where little or nothing is known of the fossil 

record so that additional attention may be given to these areas during field survey. The 

analysis should consider the likely impacts on the known or potential fossil resource and 

should be the basis for determining the need for or level of additional assessments. 

C. Determining the Need for Field Surveys and Mitigation. The previously discussed procedures 

may result in the determination that the project may encounter bedrock or an alluvial zone that has a 

moderate or high potential to contain significant paleontological resources. However, it does not 

determine the appropriate action, such as a field survey, on-site monitoring, special stipulations, 

avoidance, or other mitigation. 

1.	 If the need for further work is not clearly evident after the analysis, the Authorized Officer 

and/or Project Leader should be consulted for a final decision. The Paleontology Lead or 

Regional Paleontologist may also be consulted. A brief written report of findings should be 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

prepared, including the rationale for supporting the decision not to require a field survey or 

additional monitoring. The report should be signed by the Authorized Officer and placed in 

the project file. For example, a seismic survey using vibroseis trucks may be proposed on 

areas of deep soils, or a temporary recreational event may be planned in an area of low fossil 

potential. These types of projects are not likely to have a reasonable potential to adversely 

affect important paleontological resources. The file should be documented and a standard 

discovery stipulation attached to the permit proposal. 

2.	 If the analysis in Sec. I.B indicates a reasonably high expectation of not just encountering a 

potential fossil-bearing zone and also causing adverse impacts to significant paleontological 

resources, the determination must be made as to (1) whether adverse effects cannot be 

avoided; (2) whether the adverse impacts can be avoided by altering the location or scope of 

the project; (3) whether the impacts can be mitigated through development of special 

stipulations such as requiring on-site monitoring; or (4) whether field surveys will be 

necessary to determine the presence or absence of significant paleontological resources. 

3.	 In the case where it is known that significant paleontological resources will be adversely 

impacted, the preferred course of action is avoidance of the impact by moving or rerouting 

the site of construction, or eliminating or reducing the need for surface disturbance. 

4.	 Application of specific stipulations may reduce or eliminate adverse impacts in many cases. 

A standard discovery stipulation should be included in any permit approval that is likely to 

affect significant paleontological resources. The stipulation should mandate an immediate 

work stoppage in the area of discovery, notification to the Authorized Officer, and protection 

of the material and geological context. Other stipulations may be appropriate on a case-bycase basis. 

(a) A suggested standard discovery stipulation for a discretionary federal action is: 

The permittee shall immediately notify the BLM Authorized Officer of any paleontological 

resources discovered as a result of operations under this authorization. The permittee shall 

suspend all activities in the vicinity of such discovery until notified to proceed by the 

Authorized Officer and shall protect the discovery from damage or looting. The permittee 

may not be required to suspend all operations if activities can be adjusted to avoid further 

impacts to a discovered locality or be continued elsewhere. The Authorized Officer will 

evaluate, or will have evaluated, such discoveries as soon as possible, but not later than 10 

working days after being notified. Appropriate measures to mitigate adverse effects to 

significant paleontological resources will be determined by the Authorized Officer after 

consulting with the operator. Within 10 days, the operator will be allowed to continue 

construction through the site, or will be given the choice of either (1) following the 

Authorized Officer’s instructions for stabilizing the fossil resource in place and avoiding 

further disturbance to the fossil resource, or (2) following the Authorized Officer’s 

instructions for mitigating impacts to the fossil resource prior to continuing construction 

through the project area. 

Note: C.1 and C.2 above would be conducted at the permittee's expense. By regulation, after 

a 3809 plan of operations is approved or where there is no plan, the BLM is responsible for 

the cost of any investigation and recovery of fossil materials. 

(b) Other stipulations may be developed to reduce potential impacts, preferably in 

consultation with the project proponent. These may include (1) techniques to reduce surface 

disturbance, (2) briefings for all personnel about the potential for discovery, (3) requiring all 

finds be reported, and (3) using a "light touch" in sensitive areas. These should be made a 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

formal part of the authorization for the project and discussed at a preconstruction meeting or 

an on-site meeting in the case of oil and gas operations. 

(c) All proponents should be directed to share the current rules and regulations regarding 

fossil theft and the limitations to free use collecting of invertebrate and plant fossils on BLMadministered lands with all employees and subcontractors under their direction. Unlawful 

removal, damage, or vandalism of paleontological resources will be prosecuted by federal 

law enforcement. Theft or damage to government property by a proponent, a proponent’s 

employee, or a subcontractor that is under a proponent’s direction may lead to legal actions 

against the proponent. 

5.	 If avoidance actions or stipulating measures are insufficient to protect known paleontological 

resources, a written assessment must be completed to determine the need for field survey or 

monitoring. This assessment must include the anticipated direct or indirect impacts associated 

with the project, the inadequacies of avoidance or special stipulations to protect the resource, 

existing paleontological information and known localities, relevant geologic information, and 

the potential for additional discoveries. The assessment must be completed by the 

Paleontology Coordinator. 

(a) In some cases, bedrock will not be visible at the surface in the project area (for example, 

where thin soils or alluvium obscure all outcrops), but the proposed excavation will likely 

penetrate into bedrock with known significant paleontological resources. Because fossil 

material will not be visible at the ground surface in these cases, it may be appropriate to 

forego a field survey prior to excavation, but require on-site monitoring or spot-checks when 

bedrock is finally encountered. If construction monitoring is proposed, the written assessment 

must include a thorough justification for the recommendation. 

(b) The State Office may require the Paleontology Coordinator to notify the Paleontology 

Lead that a field survey or monitoring is deemed appropriate prior to the final decision to 

require the survey or monitoring. The notification should minimally include the name of the 

project, the legal description of the location or other locational information, a brief summary 

of the proposed action, reason(s) for the decision to require a survey or monitoring, and any 

other relevant information. Concurrence of the Paleontology Lead or Regional Paleontologist 

may be required prior to the final decision for requiring a survey or monitoring. 

(c) A standardized assessment document may be developed that can be applied to projects 

that are similar in nature, relatively small, and repetitive in approach for use within a Field 

Office or District. This written assessment is intended to simplify the documentation process 

for those projects that are likely to have minimal impacts, and may be structured as a 

programmatic assessment, a form, a checklist, or other document with standard items. This 

assessment must include the name of the project, the legal description of the location or other 

locational reference, a brief summary of the proposed action, reason(s) for the decision, and 

any other relevant information. The parameters in the assessment should be designed to 

identify the need for a field survey. For example, the parameters may indicate a field survey 

may be required for road and well pad construction activities occurring on Class 4 or 5 

formations where the formation is likely to be encountered during surface disturbing 

activities. The Field Manager, in consultation with the Paleontology Lead, must approve the 

use of a programmatic assessment prior to initial implementation. 

6.	 The decision to require a field survey or monitoring must be made by the Authorized Officer 

and documented in the project file. If required, a copy of the decision must be furnished to 

the Paleontology Lead. 

D-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

II. Procedures for Conducting a Paleontological Field Survey 

If the assessment of existing data indicates: (a) the presence or high probability of occurrence of 

vertebrate fossils or uncommon nonvertebrate fossils (PFYC Class 4 or 5), or that the probability is 

unknown (Class 3), in the area of a proposed federal action or transfer of title, and (b) a reasonable 

probability that those resources will be adversely affected by the proposed action, a paleontological 

field survey should be conducted. 

A. Definition of Field Surveys. Field Surveys are pedestrian surveys to be performed in areas where 

significant fossils can be expected to occur within the boundary and immediate vicinity of the 

anticipated disturbance, or where the probability of encountering significant fossils is unknown. 

1.	 Field surveys are performed prior to any surface disturbing activities. Before conducting field 

surveys, the project location should be as final as possible and any staking of the location 

should be complete. 

2.	 Surveys are conducted by a BLM Regional Paleontologist, Paleontology Lead, Paleontology 

Coordinator, appropriately trained and supervised BLM staff, or by a BLM-permitted 

consulting paleontologist hired by the project proponent. 

(a) At the Field Manager’s discretion, other qualified BLM staff may conduct surveys on 

small projects. Performance of surveys by BLM staff must also be approved by the Regional 

Paleontologist, Paleontology Lead, or Paleontology Coordinator. 

(b) Surveys that are complex in nature, constrained by construction schedules, or otherwise 

cannot be performed by BLM staff should be performed by a consulting paleontologist 

holding a valid BLM Paleontological Resources Use Permit. Submission of reports may be 

done directly by the paleontologist to the BLM. The project proponent is also responsible for 

all costs associated with the survey, including the consulting paleontologist’s fees and 

charges, all survey costs, fossil preparation to the basic identification stage, analyses, reports, 

and curation costs directly related to mitigation of the project’s anticipated impacts. Any 

required monitoring and mitigation costs are also the responsibility of the project proponent. 

These costs are to be negotiated between the project proponent and the consulting 

paleontologist prior to beginning any data gathering, analysis, or field work, and these 

negotiations do not require BLM involvement or approval. Any new, additional, or modified 

curation agreements between the paleontologist and the official repository must be in place 

prior to starting field work. 

(c) Authorization for an activity to proceed cannot be given by a consulting paleontologist. 

Performance of the survey, either by a consulting paleontologist or BLM staff, or submission 

of the report DOES NOT constitute approval for the activity to proceed. The BLM must 

review the report, including adequacy of the field methods and findings. The Authorized 

Officer must approve the findings and determine the need for monitoring prior to approval to 

proceed. 

B. Conducting Field Surveys. Field surveys must be performed by the Principal Investigator or an 

approved Field Agent or Field Monitor (see section IV.C., Types of Field Personnel for descriptions 

of these individuals) as authorized under a Paleontological Resource Use Permit, or by a BLM 

Regional Paleontologist or qualified BLM designee. Field surveys and collections performed as a 

mitigation measure are not intended to be scientific research studies, but are meant to identify, avoid, 

or recover paleontological resources to prevent damage or destruction from project activities. 

However, proper scientific techniques and procedures must be utilized during all mitigation efforts. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 D-17 
APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Safety should be an important consideration; therefore, surveys should not be attempted on cliff 

faces, in open, non-reinforced trenches deeper than five feet, or other unsafe areas. 

1.	 The scope of the survey is dependent upon the scale of the project. Small projects are defined 

as less than 10 acres, or, if linear, less than five miles; large projects exceed those 

dimensions. 

2.	 At the start of field work, the consulting paleontologist (paleontologist) must contact the 

Paleontology Coordinator in each affected Field Office who may require a visit to that office. 

After an initial visit each year, the paleontologist may contact the Field Office by telephone 

or email prior to subsequent field trips, at the discretion of the Field Office. Information 

about the survey schedule, additional personnel, emergency field contact information, and 

any other pertinent data should be provided to the Paleontology Coordinator. The Field 

Office will inform the paleontologist of any conditions that may impact the survey, such as 

fire danger or restrictions, drought restrictions, wildlife timing restrictions, management 

restrictions, road restrictions or construction, and any other relevant information. 

3.	 During the field survey, the paleontologist surveys, locates, and documents all 

paleontological resources within 200 feet of the proposed project location or corridor, or less 

distance upon approval. 

(a) Where significant paleontological resources are at risk, data collection alone does not 

constitute mitigation of damage. All significant fossils that may be damaged or destroyed 

during project activities must be collected, along with all relevant contextual and locational 

data. Specimens must be collected during the survey or prior to commencement of any 

surface-disturbing activities. 

(b) In many cases, isolated gar scales, chelonid (turtle) carapace or plastron fragments, 

crocodile and fish teeth, and unidentifiable bone fragments do not need to be collected. The 

location must be recorded and a description of the fossil material noted in the field notes and 

on a BLM Locality Form as part of the report. The context of these types of fossils should be 

considered, as they may represent rare occurrences or unusual faunal associations, and thus 

may be scientifically important and must be documented and voucher specimens collected 

where appropriate. 

(c) Occurrences of plant or invertebrate fossils should be recorded and representative 

examples or voucher specimens collected where appropriate. Additional mitigation measures 

may be appropriate in some cases for these types of localities. 

(d) If a large specimen or a concentration of significant fossils is located during the field 

survey, the available time and/or personnel may not allow for full recovery during the survey. 

The specimen(s) and locality(ies) should be stabilized as needed, and a determination made 

as to whether avoidance is necessary or whether full recovery of the specimen is required at a 

later time prior to disturbance activities. The Authorized Officer and project proponent must 

be notified, the mitigation alternatives discussed including funding for recovery, and a 

decision reached as soon as possible. If avoidance or later recovery is selected for mitigation, 

the find should be stabilized, buried if needed to protect the fossils and context, and 

appropriate measures implemented to reduce adverse effects from natural or human causes. 

4.	 During the survey, locations or areas that exhibit a lithology suggesting a high probability of 

subsurface fossil material must be recorded, and a recommendation for the need for on-site 

monitoring, spot-checking, or testing should be made in the report. This may include areas 

where no fossil material was found on the surface during the survey. The recommendation 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

should consider the size and type of planned disturbance, such as the depth of a trenching 

operation or the acreage of surface disturbance. 

5.	 Surveys must be performed only during times when the ground is visible and not frozen. This 

will often preclude surveys during winter months in many areas. Biological timing 

restrictions, such as critical nesting or birthing times, may confine or delay field activities. 

Project proponents should be informed of BLM’s requirement for performing any field 

surveys as soon as possible and should be advised of the possibilities for delays in survey 

completion based on seasonal weather conditions or other management restrictions to allow 

for adequate scheduling of available time. 

C. Report of Survey Findings. After completion of the field survey, the paleontologist must file a 

written report with the BLM and the designated repository. If required, a copy should also be filed 

with the project proponent. This report must summarize the results of the survey as well as 

appropriate geological and paleontological background information as described below. It should 

also include any recommendations for on-site monitoring or other mitigation. For small projects (less 

than 10 acres), the report must be filed within 30 days after completion of the survey unless specific 

approval for a different time frame has been received from the BLM. The time frame for submission 

of the report for large projects should be negotiated during project scoping. On a case-by-case basis, 

approval to begin project activities may be granted for those portions of the project area noted to be 

less paleontologically sensitive prior to final approval of the report. 

1.	 Reports of the general findings and the background information must be submitted to the 

BLM project manager or Authorized Officer (if appropriate), the Paleontology Lead or 

Regional Paleontologist, and each affected Field Office. Reports must include the following 

details, as applicable. Items (a) and (b) should appear at the beginning of the report and may 

be presented as a title page in multi-page reports. Some of these categories may be combined. 

(a) Name, affiliation, address, date of report, and permit number (if consultant) of 

paleontologist doing the survey. 

(b) Project name and number (if used), name of proponent, and general location of project. 

(c) Date(s) of survey and names of any personnel assisting with the survey. 

(d) Brief description of the proposed project, emphasizing potential impacts to 

paleontological resources. 

(e) Description of background research conducted. (Include overview of known 

paleontological information, institutions consulted, previous surveys in the area, previous 

projects of similar nature in the area, and general description of survey techniques 

employed). 

(f) Summary of regional and local geology. May reference earlier projects for relevant 

information. 

(g) Summary of regional and local paleontology. May reference earlier projects for relevant 

information. 

(h) Summary of the survey results. 

(i) Significance of findings. 

(j) Potential impacts to paleontological resources resulting from the project. 

(k) Detailed mitigation recommendations that may lessen potential adverse impacts. 

(l) Potential fossiliferous areas to allow for future assessment of sites if applicable. 

(m) Cited and other pertinent references. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

(n) Map of project area, indicating areas surveyed, known localities, and new discoveries. 

(o) Relevant photos, diagrams, tables to aid in explaining, clarifying, or understanding the 

findings. 

(p) Listing of collected material, including field numbers, field identifications, and elements, 

cross-referenced to locality field numbers. This list may be submitted in electronic format, 

preferably in spreadsheet format. 

(q) BLM locality form (8270-3) or equivalent for each new locality (including localities 

where fossils were observed but not collected) with a 1:24000 scale map showing the 

localities (not reduced in scale during photocopying) (see items 2 and 3 below). 

2.	 Exact locations of fossil localities contained in these reports are considered sensitive and 

must not be included in any public document. The BLM locality form (8270-3) or equivalent, 

1:24000 scale map showing the localities, and any other information containing specific 

fossil locations may be bound separately or placed in a separate section to allow for 

preservation of confidential locality data. A copy of this confidential section must be 

submitted to the Paleontology Lead (in some cases, two copies may be required). A copy for 

each affected Field Office may be required. Another copy must be submitted to the official 

repository with the collected materials. 

3.	 BLM GPS recording and data standards must be used to report paleontological locality data. 

Existing USGS topographic maps are often based on the NAD27 standard, so locality data 

calculated from a map base must be converted before submission. Data must be recorded and 

reported with a mean error of +/- 12.5 meters or less, at a 95 percent confidence level. For 

small localities, data should be reported as point data. Larger polygonal localities should be 

reported using coordinates of a centroid and a description of the approximate size, or the key 

coordinate points of a bounding polygon. Linear features, such as roads or surveyed project 

boundaries, must be reported as line data. The 1:24000 scale map(s) accompanying the 

locality forms should graphically illustrate the locality, either as a point or an outline of the 

locality as appropriate, and be clearly labeled with the locality or field number. 

D. Report Approval. The Authorized Officer will analyze the Survey Report for adequacy within 10 

working days of receipt. Notification accepting the report, or explaining any identified deficiencies, 

will be sent to the consulting paleontologist and the project proponent with a copy placed in the 

project file. Any deficiencies must be corrected as soon as possible, usually initiated within five 

working days, and the report must be resubmitted for approval. Any resubmissions must be prompt, 

but consideration will be made for the amount of time needed for major corrections. Deficiencies 

directly affecting the survey, such as inadequate survey procedures or incomplete data, must be 

corrected before granting approval for the project to proceed. Deficiencies not directly affecting the 

survey, such as curation issues, will not prevent approval of the project, but must be corrected as 

soon as possible. 

III. Determination of Further Mitigation Requirements 

The need for additional mitigation to protect paleontological resources will be determined on a caseby-case basis. The Authorized Officer, in consultation with Regional Paleontologist or the 

Paleontology Lead, will analyze the Survey Report for survey findings and any mitigation 

recommendations. If no further mitigation is needed, the Authorized Officer will promptly notify the 

project proponent that there are no additional paleontological surveys or mitigation measures 

required, and the project may proceed pending any other approvals. The project file must be 

documented indicating acceptance of the survey report and identifying any additional mitigation 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

requirements. If it is determined that additional mitigation efforts are needed to protect or preserve 

the paleontological resources, the project proponent will be notified as soon as possible. The 

Authorized Officer and/or the Paleontology Lead usually develop and approve the mitigation 

procedures or recommend a project be redesigned in consultation with the project proponent. Factors 

such as locality or specimen significance, economics, safety, and project urgency will be considered 

when developing mitigation measures. Additional mitigation measures will be developed and 

implemented as timely as possible so as not to delay project actions. 

A. Relocation. The preferred mitigation technique is to change the project location based on the 

results of the field survey. Relocation, however, may necessitate a field survey of the new area, as 

well as resurveys by other resource specialists. Anticipation of this contingency prior to or during the 

original survey may allow for survey of an expanded area at the same time. If relocation will 

eliminate impacts and is acceptable to all parties, then a report to the file, including a map showing 

the original and revised locations, must be completed documenting the change. Approval for the 

project to proceed in the revised location may then be granted by the Authorized Officer to the 

project proponent. When avoidance is not possible, appropriate mitigation may include excavation or 

collection (data recovery), stabilization, monitoring, protective barriers and signs, or other physical 

and administrative protection measures. 

B. Deferred Fossil Collection. In some cases, fossil material may have been identified, but not 

completely collected during the initial field survey, such as a partial dinosaur or other large fossil 

assemblage. It may be possible to complete the recovery of this material and all related data prior to 

beginning construction activities, and thus mitigate the adverse impact. This may require a shift in 

the project schedule and must be coordinated with the project proponent. Approval by the Authorized 

Officer for the project to proceed will only be granted when recovery of the fossil material and field 

data is completed. A report to the file and the project proponent documenting the recovery and 

indicating that no further mitigation is required must be completed, and the report signed by the 

Authorized Officer. If the discovery cannot be fully collected within the available time frame, it may 

have to be avoided by relocating or redesigning the project. 

IV. Procedures for Field Monitoring 

The purpose of on-site monitoring is to assess and collect any previously unknown fossil material 

uncovered during the project activities or soon after surface-disturbing actions. Based on the initial 

scoping, the field survey and recommendations, and the plan of operations, it may be necessary to 

require monitoring of surface-disturbing activities. Monitoring may be required as part of an overall 

mitigation for a project which was developed during the NEPA process, or upon the discovery of 

paleontological resources during project activities. 

A. Monitoring Plan. A monitoring plan can be developed by a BLM paleontologist or a qualified 

paleontologist hired by the proponent. The plan must be appropriately scaled to the size and 

complexity of the anticipated monitoring. If developed by a third party, the appropriate Paleontology 

Lead or Regional Paleontologist shall review the plan for sufficiency prior to acceptance. Monitoring 

of the project may proceed when the monitoring plan is approved by the Authorized Officer. A 

monitoring plan indicates the treatments recommended for the area of the proposed disturbance and 

must minimally address the following: 

1.	 The recommended approach to additional specimen collection, such as total or partial 

recovery or sampling; and
 

2.	 The specific locations and intensity of monitoring or sampling recommended for each 

geologic unit, stratigraphic layer, or area impacted. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

3.	 Monitoring intensity is determined based on the analysis of existing data and/or field surveys 

and any previous monitoring efforts. 

B. Types of Monitoring. There are two types of monitoring: 1) on-site, performed during ongoing 

operations, and 2) spot-checks, performed during or after disturbance, or at key times during the 

progress of the project. 

1.	 On-site monitoring – In areas with a high probability for buried fossils, the presence of a 

monitor at the site of disturbance at all times that disturbance is occurring may be warranted. 

The need for a full-time monitor is based on the findings of the survey, the local geology, and 

the proposed actions. Efforts will be made to complete fossil recovery with minimal work 

stoppage. However, in some cases, an extended period of work stoppage may be required, so 

coordination with the project proponent or representative is important (see D below). Prior to 

beginning the monitoring work, the monitor, company supervisor, and machinery operators 

should agree on procedures for brief work stoppages to allow for examination of finds. It is 

critical that safety be of utmost concern because of the presence of heavy machinery and 

open trenches. 

1.	 The monitor must assess any finds, collect loose fossil material and related data, and take 

appropriate steps to mitigate any current or potential damage. Consideration of the size of the 

expected fossils must also be considered; for example, microfossils may not be visible during 

excavation activities. It may be appropriate to collect samples of matrix for later recovery of 

microvertebrate fossils or other analyses. Activities planned to occur during night time 

should be assessed relative to the potential to uncover significant fossils. Fossils may not be 

visible at night in trenching or grading operations, so construction activities may need to be 

suspended during night time in sensitive areas. 

2.	 Spot-checking – In areas with a moderate to high probability for unknown fossil material, it 

may be more appropriate to check only at key times rather than maintain continuous 

monitoring of operations. Key times for scheduling spot-checking are when the fossil-bearing 

bedrock is exposed to view or prior to placing spoil material back into the excavation. 

Examples of these key times may be when a pipeline trenching operation is complete but 

before pipe is placed and the trench backfilled or prior to redistribution of topsoil. Spotchecking requires close coordination with the project proponent and the paleontologist, and 

usually requires the paleontologist to be available on short notice. In some instances, it may 

be advantageous to allow rain and/or wind to erode away loose matrix and concentrate fossil 

material to increase visibility. The paleontologist will coordinate with the project proponent 

to allow sufficient time for this action to occur, as appropriate to conditions, expected fossil 

material, and construction schedules. 

3.	 The paleontologist should report potentially fossiliferous areas in the final report to allow for 

future assessment of sites, even if no fossils were located during the project monitoring. 

C. Types of Field Personnel. Depending on the complexity of the project, it may be necessary to 

employ a number of paleontology field personnel simultaneously. There may be a lack of fully 

qualified paleontologists to perform all the necessary monitoring during the scheduled times of 

construction. Use of additional personnel for field work is permissible, but Field Agents and Field 

Monitors (described below) must be requested by the Permittee and authorized by the BLM prior to 

field work. 

1.	 Principal Investigator – The person listed as Permittee (Permit item 1a) on the 

Paleontological Resources Use Permit is the Principal Investigator (PI) and is responsible for 

all actions under the permit, for meeting all permit terms and conditions, and for the 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

performance of all other personnel. This person is also the contact person for the project 

proponent and the BLM. 

2.	 Field Agent – Other qualified paleontologists may perform field work independently of the 

PI under the conditions of this permit. Résumés must be submitted to BLM and must 

demonstrate qualifications equivalent to those of Permittees. Field Agents must be listed on 

the permit under “Name(s) of individual(s) responsible for planning, supervising, and 

carrying out fieldwork” (Permit item 8) or authorized in a separate letter from BLM. They 

must follow all the permit terms and conditions applicable to field work and must carry a 

copy of the permit, included terms and conditions, and separate authorizing letter (if used) 

while in the field. Field work results must be reported to the PI, who will then submit 

required reports. 

3.	 Field Monitor – Field Monitors may be utilized for supplemental on-site monitoring of 

surface-disturbing activities when the PI or a Field Agent is performing field work elsewhere. 

Field Monitors must have sufficient field experience to demonstrate acceptable knowledge of 

fossil identification, collection methods, and paleontological techniques. The PI must supply 

a summary of each person’s experience to the BLM prior to field work. Field Monitors must 

be approved by the BLM prior to performing field work and must carry a copy of the permit 

while in the field. The PI or Field Agent must be in communication with the Field Monitor 

using a portable communication device, such as a cell phone or two-way radio, and are 

required to be near enough to the Field Monitor to allow for prompt examination of all fossil 

discoveries (no more than two hours away) by the PI or Field Agent. 

4.	 Field Assistant – Additional personnel not meeting the previously cited experience or 

knowledge levels may be utilized during field work, but must be under direct, on-site 

supervision of either the PI or a Field Agent as part of a supervised crew. Field assistants 

must have at least four to eight hours of training or experience received from a qualified 

paleontologist in identifying paleontological resources prior to performing field work or 

when first utilized in this capacity. A listing of all Field Assistants (including contact 

information) must be supplied prior to any field work. All discoveries made by a Field 

Assistant must be immediately reported to the PI or Field Agent on site. To ensure proper 

supervision, an appropriate ratio of Field Assistants per PI or Field Agent must be 

maintained. The complexity of the project, the area to be covered, and the experience of the 

assistants are some of the factors that should be considered in determining the proper ratio, 

but commonly five to seven assistants is the maximum number that can be supervised by one 

PI or Field Agent. 

D. Work Stoppage. If significant fossil material is discovered during construction activities, the PI, 

Field Agents, and Field Monitors have the authority to temporarily halt surface disturbing actions 

until an assessment of the find is completed and appropriate protection measures taken. Efforts will 

be made to complete fossil recovery with minimal work stoppage. However, in some cases, an 

extended period of work stoppage may be required. If the paleontological resource can be avoided, 

mitigated, or collected within approximately two hours, work may resume after approval from the PI 

or Field Agent, and the Authorized Officer must be notified as soon as possible of the discovery and 

any mitigation efforts that were undertaken. If the find cannot be mitigated within a reasonable time 

(two hours), the concurrence of the Authorized Officer or official representative for a longer work 

stoppage must be obtained. Work may not resume until approval is granted from both the PI or Agent 

and the Authorized Officer. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

V. Final Project Report 

Upon completion of all field work, including survey and monitoring, the PI must submit within 30 

days, a written final report to the Authorized Officer, Paleontology Lead, and the designated 

repository. A copy of the report may be provided to the project proponent if required, but without the 

BLM Locality forms. Reports must include the following details. Items 1 and 2 should appear at the 

beginning of the report, and may be presented as a title page in multi-page reports. 

1.	 Name, affiliation, address, date of report, and permit number (if consultant) of the 

paleontologist doing the survey. 

2.	 Project name and number (if used), name of proponent, and general location of project. 

3.	 Date(s) of the survey and names of any personnel assisting with the survey. 

4.	 Brief description of project and expected impacts to paleontological resources. 

5.	 A summary of mitigation performed. 

6.	 A summary of findings, including important discoveries. 

7.	 A description of potentially fossiliferous areas to allow for future assessment of sites, even if 

no fossils were located during the project monitoring. 

8.	 A completed BLM locality form 8270-3 or equivalent for each new locality using Universal 

Transverse Mercator (UTM) NAD 83 coordinates, and 1:24000 scale maps with new 

localities plotted using points or polygons as appropriate. Locality forms, maps, and any 

other information containing specific fossil locations should be bound separately or 

assembled as a separate section to allow for preservation of confidential locality data. 

9.	 List of specimen field numbers and field identifications of collected material, crossreferenced to the locality field number. This list may be submitted in electronic format, 

preferably in a spreadsheet format. 

If the survey was performed by BLM, a report similar in contents must be written and filed in the 

project file, and the project proponent notified as soon as possible upon completion. 

VI. Completion of Mitigation Responsibility 

When the final report with the specimen inventory and the signed receipt of confirmation of museum 

deposition are accepted by the BLM, mitigation for paleontological resources related to the project 

will be considered completed. The project proponent will be notified in writing as soon as possible 

by the Authorized Officer after consulting with the Paleontology Lead or Regional Paleontologist 

and a copy of the notification placed in the project file. 

The responsibility of the project proponent ends when appropriate mitigation related directly to the 

project is completed and final approval is received from the Authorized Officer. Any additional field 

collection, quarrying, final specimen preparation, etc. will be considered to be research, and will be 

the responsibility of the consulting paleontologist or another approved party. The project proponent 

will not be held responsible for completion of any research project. However, the project proponent 

can choose to sponsor further research. A separate research permit will be required for additional 

research activities. 

VII. Collections Resulting from Assessment and Mitigation 

Fossil specimens and related data collected from public lands during field surveys and mitigation 

remain the property of the Federal government. They must be placed in the approved repository(s) 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

identified on the Paleontological Resource Use Permit held by the consulting paleontologist as soon 

as practical and receipt(s) of collections submitted to the BLM, but no later than 60 days after all 

field work is completed. Written approval from the Paleontology Lead or Regional Paleontologist is 

required if additional time is needed for transfer of all specimens and field data. 

VIII. Resource Management Updates 

Based on findings resulting from any of the above steps, the project file, locality and specimen 

information, and other BLM data should be updated to reflect any new or modified information. 

Paleontology permit files should be checked and updated, as well as any other administrative information. 

The PFYC Class assignments can be assessed based on the analysis, survey, and monitoring results. New 

information may indicate a change in the PFYC Class is appropriate for one or several geologic units. 

Other applications of the PFYC system should be considered, such as the use for impact analyses in 

planning documents or for survey and mitigation determinations for other projects. Any changes in 

classification must be made in consultation with the Paleontology Lead or Regional Paleontologist to 

maintain consistency across Field Office boundaries. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Appendix A to Attachment 1 – Definitions 

(As applicable to BLM management of paleontological resources) 

Alluvium – A general term for clay, silt, sand, gravel, or similar unconsolidated detrital material 

[fragments of rock or mineral material derived from older rocks] deposited during relatively 

recent geologic time by a stream or other body of running water as a sorted or semi-sorted 

sediment in the bed of the stream or its flood plain or delta, or as a cone or fan at the base of a 

mountain slope; especially, such a deposit of fine-grained texture (silt or silty clay) deposited 

during a time of flood (from American Geological Institute (AGI), Glossary of Geology, 

1972 ed.) 

Alluvium may contain paleontological resources in older alluvial deposits. The location on 

the landscape often will provide clues to the potential for paleontological resources within 

alluvial deposits. As an example, alluvium developed near major river courses or lake 

margins has a much higher potential to contain significant paleontological resources than 

alluvium (colluvium) formed from slope wash. 

Approved Repository – Meets the Department of the Interior 411 Departmental Manual (DM) 

provisions for museum property, including capability for providing adequate long-term 

curatorial services, such as a physically secure environment, and maintaining professional 

staff qualified to catalog, care for, preserve, retrieve, and loan, where appropriate, these 

materials and associated records. 

Bedrock – A general term for the rock, usually solid, that underlies soil or other unconsolidated, 

surficial material (from American Geological Institute (AGI), Glossary of Geology, 1972 ed.) 

For paleontological purposes, bedrock generally excludes alluvium, colluvium, sand dunes, 

and loess (fine-grained blanket deposit of marl or loam). In certain situations, bedrock may 

contain recent soils/sediments with fossils. 

Colluvium – A general term applied to any loose, heterogeneous, and incoherent mass of soil 

material or rock fragments deposited chiefly by mass-wasting, usually at the base of a steep 

slope or cliff; e.g., talus, cliff debris, and avalanche material. Also, alluvium deposited by 

unconcentrated surface run-off or sheet erosion, usually at the base of a slope (from 

American Geological Institute (AGI), Glossary of Geology, 1972 ed.) 

Field Agent – Other qualified paleontologists may perform field work independently of the PI under 

the conditions of this permit. Résumés must be submitted to BLM and must demonstrate 

qualifications equivalent to those of Permittees. Field Agents must be listed on the permit 

under “Name(s) of individual(s) responsible for planning, supervising, and carrying out 

fieldwork” (Permit item 8) or authorized in a separate letter from BLM. They must follow all 

the permit terms and conditions applicable to field work and must carry a copy of the permit, 

included terms and conditions, and separate authorizing letter (if used) while in the field. 

Field work results must be reported to the PI, who will then submit required reports. 

Field Assistant – Additional personnel not meeting the previously cited experience or knowledge 

levels may be utilized during field work, but must be under direct, on-site supervision of 

either the PI or a Field Agent as part of a supervised crew. Field assistants must have at least 

4 to 8 hours of training or experience received from a qualified paleontologist in identifying 

paleontological resources prior to performing field work or when first utilized in this 

capacity. A listing of all Field Assistants (including contact information) must be supplied 

prior to any field work. All discoveries made by a Field Assistant must be immediately 

D-26 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

reported to the PI or Field Agent on site. To ensure proper supervision, an appropriate ratio of 

Field Assistants per PI or Field Agent must be maintained. The complexity of the project, the 

area to be covered, and the experience of the assistants are some of the factors that should be 

considered in determining the proper ratio, but commonly five to seven assistants is the 

maximum number that can be supervised by one PI or Field Agent. 

Field Monitor – Field Monitors may be utilized for supplemental on-site monitoring of surfacedisturbing activities when the PI or a Field Agent is performing field work elsewhere. Field 

Monitors must have sufficient field experience to demonstrate acceptable knowledge of fossil 

identification, collection methods, and paleontological techniques. The PI must supply a 

summary of each person’s experience to the BLM prior to field work. Field Monitors must be 

approved by BLM prior to performing field work and must carry a copy of the permit while 

in the field. The PI or Field Agent must be in communication with the Field Monitor using a 

portable communication device, such as a cell phone or two-way radio, and are required to be 

near enough to the Field Monitor to allow for prompt examination of all fossil discoveries 

(no more than two hours) by the PI or Field Agent. 

Field Survey – Pedestrian (walking) surveys performed in areas where significant fossils are 

expected to occur within the boundary or immediate vicinity of an anticipated disturbance. 

Surveys are performed by a qualified paleontologist or BLM Regional Paleontologist or other 

officially appointed BLM employee prior to any surface disturbing activities. Survey 

activities also include concurrent collection of significant fossils. 

Land Tenure Adjustments/Change in Title – Changes in ownership or administration of surface or 

mineral estates, typically exchanges or sales, which may result in a change in ownership or 

control of paleontological resources. 

Monitoring – a) On-site observation during all surface disturbing activities to assess and collect any 

previously-unknown fossil material uncovered by the project activities. b) Examination of 

excavation or spoil piles at key times during project activities. Monitoring must be performed 

by a permitted paleontologist, field agent, or field monitor (see section IV.C.), Regional 

Paleontologist, or other officially appointed BLM employee, and occurs during or soon after 

surface disturbing actions. 

Paleontological Locality (Locality) – A geographic point or area where a fossil or associated fossils 

are found in a related geological context. A paleontological locality is confined to a discrete 

stratigraphic layer, structural feature, or physiographic area. 

Paleontology Program Coordinator (Paleontology Coordinator) – The employee designated by 

the local BLM Office Manager to manage paleontological resource issues, including 

planning, mitigation, budget, and other administrative duties. The local point of contact for 

paleontological resource use permittees, the State Office Paleontology Program Lead, and the 

Regional Paleontologist. The employee is usually a geologist or archaeologist. 

(a) In some offices, additional employees may be designated by the supervisor to determine 

the need for field surveys and monitoring for some projects, or other duties in support of 

the paleontology program. The scope of duties for these additional employees must be 

approved by the Paleontology Program Lead and closely coordinated with the 

Paleontology Coordinator. 

(b) A few current BLM employees may meet the same professional qualifications that are 

required for a BLM Paleontological Resources Use Permit applicant. BLM-approved 

training and field experience may also allow employees to gain sufficient background to 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 D-27 
APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

achieve competency in the field. With the approval of the Regional Paleontologist and the 

Office Manager or Deputy State Director, these employees may be designated as 

qualified to perform field surveys or monitoring. The current availability of these 

employees must also be approved by the unit manager or Deputy State Director, typically 

on a project-by-project basis or within a defined time period. Depending on official 

duties, local roles and responsibilities, and management preferences, these employees 

may or may not be the Paleontology Coordinator. 

Paleontology Program Lead (Paleontology Lead) – Any one of the following: the Regional 

Paleontologist in the states with an identified position; the paleontologist at Grand StaircaseEscalante National Monument; or the State Office Archeologist in the states without a 

Regional Paleontologist. 

Principal Investigator – The person listed as Permittee (Permit item 1a) on the Paleontological 

Resources Use Permit is the Principal Investigator (PI) and is responsible for all actions 

under the permit, for meeting all permit terms and conditions, and for the performance of all 

other personnel. This person is also the contact person for the project proponent and the 

BLM. 

Regional Paleontologist – The BLM paleontologist that provides professional expertise in 

paleontology, and is responsible for interpreting relevant laws, authorities, and policy for the 

administration of the BLM paleontology program for all States in his/her respective region, 

and as the program interface between Field and/or District Offices, State Offices, and the 

Washington Office. In some cases, the Regional Paleontologist also serves as the State Office 

Paleontologist. 

Significant Paleontological Resource (syn. Significant Fossil Resource) – Any paleontological 

resource that is considered to be of scientific interest, including most vertebrate fossil 

remains and traces, and certain rare or unusual invertebrate and plant fossils. A significant 

paleontological resource is considered to be scientifically important because it is a rare or 

previously unknown species, it is of high quality and well-preserved, it preserves a 

previously unknown anatomical or other characteristic, provides new information about the 

history of life on earth, or has identified educational or recreational value. Paleontological 

resources that may be considered to not have paleontological significance include those that 

lack provenience or context, lack physical integrity because of decay or natural erosion, or 

that are overly redundant or are otherwise not useful for research. Vertebrate fossil remains 

and traces include bone, scales, scutes, skin impressions, burrows, tracks, tail drag marks, 

vertebrate coprolites (feces), gastroliths (stomach stones), or other physical evidence of past 

vertebrate life or activities. 

Soil – The natural medium for growth of land plants (from American Geological Institute (AGI), 

Glossary of Geology, 1972 ed.) Generally, well-developed soils do not contain 

paleontological resources. However, the C horizon (the substratum above bedrock that is 

little affected by soil forming processes) may occasionally contain Pleistocene-aged fossils. 

Stipulations – Written conditions that may restrict or impose limits on approved activities, or require 

that certain procedures be followed. The general usage herein encompasses several formal 

terms specific to other use authorizations such as Mitigation, Terms and Conditions, 

Conditions of Approval, and Standard Stipulations. 

Surface disturbance – Disruption of the ground surface and subsurface. Disruption may damage or 

destroy significant paleontological resources and their geological context. 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

– Generally excludes: fire (but not fire activities, see below), vegetation mowing, weed 

spraying, grazing, natural erosion, fence building 

– Some activities that may impact the ground surface and must be assessed on a case-by-case 

basis are: 

•	 Mechanized vegetative treatments – chaining, sagebrush chopping, etc 

•	 Seismic activities – vibroseis techniques, cross-country travel 

•	 Fire management activities – line building, brush removal and thinning using 

mechanized equipment 

•	 Recreational activities – OHV, rock collecting, mountain biking, public events 

Voucher Specimen – A representative sample that verifies the kind of fossil material found during a 

field survey, and is collected and curated in an approved repository along with its associated 

field data. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 D-29 
APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Attachment 2. 

Paleontological Resources Assessment Flowchart 

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APPENDIX D—PALEONTOLOGICAL RESOURCES PROGRAM GUIDANCE 

Paleontological Actions 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 D-31 
 

 

 

 APPENDIX E: RECLAMATION GUIDANCE 

Table of Contents 

Introduction .......................................................................................................................................... E-3 

Appendix 36 to the Rawlins RMP (December 24, 2008) ....................................................... E-5 

High Desert District Policy for Reclamation of Disturbed Lands, 

IM WY-2012-005 (May 30, 2012) ...................................................................................... E-15 

Wyoming BLM State Reclamation Policy IM WY-2012-032, and attachments
 

(March 27, 2012) ............................................................................................................... E-17 

Proposed Interim Rollover Objective for the Continental Divide-Creston 

Natural Gas Project Environmental Impact Statement and Record of 

Decision (February 25, 2011) ......................................................................................... E-25 

Continental Divide-Creston Interim Rollover Reclamation Criteria .................................. E-43 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-1 
 

 

 

APPENDIX E—RECLAMATION GUIDANCE
 

INTRODUCTION 

This appendix was developed to provide a comprehensive source for the pertinent guidance and 

requirements of the BLM for the reclamation of surface disturbance in the CD-C project area. The 

documents in this appendix can be used by CD-C Operators to develop reclamation plans for their 

proposed development that would meet the requirements of the BLM and lead to restoration of disturbed 

sites on public lands. 

The documents in this appendix include: 

	 Appendix 36 to the Rawlins RMP. This document lays out the basic requirements for reclamation 

of surface disturbance in the RFO. The RMP was published in December 2008 and Appendix 36 has 

been in use since that time. It provides information needed to develop a reclamation plan and to 

prepare monitoring reports and explains the criteria for final reclamation success, including: 

establishment of eighty percent of pre-disturbance ground cover; 90 percent dominant species; no 

noxious weeds; and erosion features equal to or less than surrounding area. 

	 High Desert District Policy for Reclamation of Disturbed Lands. The district policy formally 

adopts and implements the Wyoming BLM State Reclamation Policy (IM WY-2012-032).
 

Additionally, it underlines the importance of on-the-ground reclamation success and cautions 

against requiring more reclamation planning information than is necessary.
 

	 Wyoming BLM State Reclamation Policy, IM WY-2012-032 and attachments. This document 

identifies ten requirements that must be addressed when developing reclamation proposals for all 

surface-disturbing activities on public lands in Wyoming. They are: 

1.	 Manage all waste materials. 

2.	 Ensure subsurface integrity, and eliminate sources of ground and surface water 

contamination. 

3.	 Re-establish slope stability, surface stability, and desired topographic diversity. 

4.	 Reconstruct and stabilize water courses and drainage features. 

5.	 Maintain the biological, chemical, and physical integrity of the topsoil and subsoil. 

6.	 Prepare site for revegetation. 

7.	 Establish desired self-perpetuating native plant community. 

8.	 Reestablish a complementary visual composition. 

9.	 Manage invasive plants. 

10. Develop and implement a reclamation monitoring and reporting strategy. 

	 Proposed Interim Rollover Objective for the Continental Divide-Creston Natural Gas Project 

Environmental Impact Statement and Record of Decision (February 25, 2011). This document 

was developed by the CD-C Reclamation Work Group, an ad hoc group focused on improving 

reclamation in the CD-C project area. The document was intended to provide flexibility for industry, 

while maintaining healthy, desirable vegetation within the project area. The group, including 

representatives of industry, state agencies, the University of Wyoming, local governments, and the 

BLM, worked for two years to develop the document. The document provided the framework in 

which the BLM Rollover Criteria, Continental Divide–Creston Draft EIS (description follows) was 

developed. 

	 BLM Rollover Criteria, Continental Divide–Creston Draft EIS. The criteria described in this 

document are formally incorporated as an element of Alternative C: Surface Disturbance Cap—High 

and Low Density Development Areas. For the purposes of the CD-C EIS, the standards and guidance 

contained in the Rawlins RMP Appendix 36 and the Wyoming State Reclamation Policy, IM-WY2012-032, apply to the Proposed Action and the other action alternatives. However, a specific 

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APPENDIX E—RECLAMATION GUIDANCE
 

exception is made with regard to rollover credits involved with Alternative C. Rollover credits exist in 

the context of a cap on the amount of surface disturbance generated by natural gas development. They 

refer to the process by which acreage that counted against a surface disturbance cap when natural gas 

facilities were initially constructed could be successfully reclaimed and rolled over, meaning counted 

again as undisturbed acreage. When a natural gas well pad and its associated road and pipeline are 

constructed, the initial disturbance is much larger than what is needed for the long term. After the 

well has been completed, the area that was initially disturbed but is no longer needed, perhaps 60 

percent of the total, undergoes interim reclamation.1

 With a surface disturbance cap in place, this 

portion of the initial disturbance acreage can be rolled over when the BLM determines that it has been 

successfully reclaimed. 

In some cases, for example in the neighboring Atlantic Rim Natural Gas Project, the success criteria 

applied for rollover credits are the same as the final reclamation standard, in other words, the RMP 

Appendix 36 performance criteria: establishment of 80 percent of pre-disturbance ground cover; 90 

percent dominant species; no noxious weeds; and erosion features equal to or less than surrounding 

area. For the CD-C Alternative C, however, the RFO has defined Reclamation Rollover Criteria as 

follows: 

o The area is re-vegetated with a stable, approved plant community; 

o Vegetative cover is sufficient to maintain a healthy, biologically active topsoil; 

o Erosion is controlled; 

o Habitat, visual and forage loss is minimized; and 

o No noxious weeds are present. 

There is no requirement that pre-disturbance ground cover or the dominant species match a specified 

percentage. Once these criteria have been satisfied in the judgment of the RFO, the affected acreage 

would be rolled over and the cap would increased by that amount. 

1 As defined in IM WYD- 03-2011-02, “interim reclamation is used to restore vegetation, and scenic and habitat 

resources while a well continues to produce energy. With interim reclamation, all areas not needed for the 

production of oil and gas are reclaimed, that is, reshaped, covered with topsoil, and reseeded with native plants. 

Interim reclamation also refers to the stabilization of soil by revegetation on sites that will likely be further disturbed 

in the future. This includes sites where recontouring is needed where periodic disturbance may occur due to 

operation and maintenance activities.” Interim reclamation can be contrasted with final reclamation, which is 

“reclamation of an area that is not planned for further disturbance including recontouring, stabilization of soil by revegetation and restoring the ecosystem function originally found at the site.” It normally occurs after a well is 

plugged and abandoned. 

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APPENDIX E—RECLAMATION GUIDANCE
 

Appendix 36, Rawlins RMP 

Reclamation of public land will be required for any surface-disturbing activity. A reclamation plan 

appropriate in detail and complexity, and tailored to a specific surface-disturbing activity, will be required 

and made a condition of approval of any action. This appendix details the elements that need to be 

considered during pre-disturbance authorization of any surface disturbance and the post-disturbance steps 

required to assure timely and proper recovery of the site. 

The reclamation plan will provide a framework to develop project-specific and site-specific reclamation 

actions and guide land management efforts toward a planned future condition for any surface disturbance. 

Early coordination between the Bureau of Land Management (BLM) and project proponents is necessary 

to produce a comprehensive plan. The reclamation plan will serve as a binding agreement between project 

proponents and BLM for the expected reclamation condition of the disturbed lands and must be 

periodically reviewed and modified as necessary. The reclamation plan will include sufficient monitoring 

requirements, reports, and components to ensure the reclamation plan is current. 

Although the proponent will usually develop the reclamation plan, appropriate BLM involvement in 

preplanning, data inventory, and approval is essential to develop the optimum reclamation proposal. Most 

determinations regarding what is expected should be made before the reclamation plan is approved and 

implemented. However, any plan can be modified to adjust to changing conditions or to correct for an 

oversight. An approved reclamation plan and reporting obligations will be required prior to any surfacedisturbing activity. A reclamation plan should provide the following: 

 A logical sequence of steps for completing the reclamation process 

 The specifics of how reclamation standards will be achieved 

 An estimate of specific costs of reclamation 

 Sufficient information for the development of a basis of inspection and enforcement of 

reclamation and criteria to be used to evaluate reclamation success and reclamation bond release 

 Sufficient information to determine whether the reclamation plan is in conformance with the 

applicable BLM land-use and activity plans, as appropriate. Further guidance for reclamation can 

be found in the BLM/Forest Service Surface Operating Standards and Guidelines for Oil and Gas 

Exploration and Development (Gold Book), fourth edition, 2006, at http://www.blm.gov/bmp/ 

gold percent20book/FinalGoldBook percent20-percent202006 percent20Edition.pdf. 

In preparing and reviewing reclamation plans, BLM and the project proponent must set reasonable, 

achievable, and measurable reclamation goals that are not inconsistent with the established land-use 

plans. Achievable goals will ensure reclamation and encourage operators to conduct research on different 

aspects of reclamation for different environments. These goals should be based on available information 

and techniques, should offer incentives to both parties, and should, as a result, generate useful information 

for future use. 

The purposes of the reclamation plan are as follows: 

	 Reclamation plans provide detailed guidelines for the reclamation process and fulfill federal, 

state, county, and other local agencies requirements. They can be used by regulatory agencies in 

their oversight roles to ensure that the reclamation measures are implemented, are appropriate for 

the site, and are environmentally sound. 

	 Reclamation plans will be used by the project proponent throughout the operational period of the 

project and subsequent to cessation of surface-disturbing activities. In turn, responsible agencies, 

including BLM, will use the reclamation plan as a basis to review and evaluate the success of the 

reclamation program. 

	 Reclamation plans should provide direction and standards to assist in monitoring and compliance 

evaluations. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-5 
 

APPENDIX E—RECLAMATION GUIDANCE
 

BLM reclamation goals emphasize eventual ecosystem reconstruction that returns the land to a condition 

approximate to or better than that which existed before it was disturbed, by re-creating the successional 

pathway that restores the plant cover and species composition of the site to its pre-disturbance direction 

and boundaries. 

Interim reclamation is an intentional activity to initiate or accelerate the recovery of an ecosystem with 

respect to its health, integrity, and sustainability, including quickly stabilizing disturbed areas to protect 

both disturbed and adjacent undisturbed areas from unnecessary degradation. 

Interim reclamation measures are used to achieve this short-term goal while setting the stage for final 

recovery. For example, on a well pad where drilling is completed, interim reclamation would include 

drying and back-filling reserve pits, initial recontouring and redistribution of saved top soil, installing a 

rocked driveway, installing fencing as needed, and revegetating the area. Interim reclamation guidelines 

will be addressed on a case-by-case basis, as appropriate. 

Final reclamation measures are used to achieve the recovery goal. A disturbed area has recovered—and is 

restored—when it contains sufficient biotic and abiotic resources to continue its development and 

interactions without further assistance or subsidy. It will demonstrate resilience to normal ranges of 

environmental stress and disturbance. 

Planning efforts that consider the processes necessary for successful reclamation are important. Predisturbance surveys, site stabilization, weed control, and maintenance and health of soils are significant 

considerations. All forms of revegetation must consider vegetative succession patterns and processes. 

Annual monitoring and reporting is the best way to track success and implement adaptive management 

strategies that treat problems. 

The ideal starting point for reclamation is to ensure that reclamation planning starts before disturbance 

and is an integral part of the operational plan. All attempts should be made to develop and implement new 

ideas and technologies that limit or greatly reduce the amount of land surface disturbance. 

Pre-disturbance surveys provide data that allow for proper planning and timely implementation of 

planned activities. For instance, pre-disturbance site surveys give the operator the information to know 

what plant communities, composition, structure, and successional pathway to restore to and can influence 

the amount and type of seed that is ordered and how and where the seed is planted and handled. Predisturbance inventories define baseline conditions and should be followed up with annual monitoring. 

Among items to be emphasized in achieving these goals are: 

 Stabilization of disturbed soils 

 Soil stabilization through establishment of a vegetative ground cover on disturbed sites during the 

first growing season following disturbance 

 Restoration of the same native vegetation disturbed or removed or restoration of an alternate 

vegetative regime in consultation with and approval by BLM’s Rawlins Field Office 

 Provide vegetation and/or site characteristics to accommodate previous land uses 

 Minimal disturbance of the existing environment and avoidance of riparian areas 

 Annual monitoring, detection, and control of invasive and noxious weeds beginning the first 

season of disturbance 

 Monitoring and management of reclamation sites to evaluate weed populations, reclamation 

success, and to plan and report on the program annually 

 Positive efforts to resist the spread of weeds, including power washing of machinery and 

equipment between work sites consistent with the Rawlins Weed Prevention Plan (USDI, BLM 

1999b). 

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APPENDIX E—RECLAMATION GUIDANCE
 

SOIL 

Topsoil is the building block of successful reclamation. Soil consists of living organisms that must be 

properly cared for. Many plants rely on these organisms to facilitate the uptake of nutrients and water, 

especially in times of stress. To preserve and care for topsoil organisms, there are several strategies that 

can be employed—stockpiled soil can be immediately planted with a mix of native plant species, 

inoculated after being respread and planted with early successional species, or stored for short periods of 

time. 

Topsoil should be handled separately from subsoil materials. At all construction sites, if topsoil must be 

stripped, project proponents must provide for sufficient quantities to be respread to a depth of at least 4 to 

6 inches over the disturbed areas during reclamation. In areas where deep soils exist (such as floodplains 

and drainage channel terraces), at least 12 inches of topsoil should be salvaged. Where soils are shallow 

or where subsoil is stony, as much topsoil should be salvaged as possible. Care should also be taken to 

avoid mixing productive soil types with less productive soil types where two or more soil types may 

occur on a single site. 

The salvaged soil can either be stockpiled for later use or used immediately over regraded surfaces that 

are ready for reclamation. The latter option, sometimes called direct or live haul, is preferable to 

stockpiling because the soil microbes, bacteria, viable seeds, and plants that can take root are at their most 

abundant, leading to better revegetation. Stockpiling soil for long periods results in the loss or elimination 

of these beneficial characteristics, especially when soils are stockpiled more than several feet high 

diminishing biological activity as a result of lack of oxygen. 

Topsoil will be stockpiled separately from subsoil materials to preclude contamination or mixing, and 

topsoil stockpiles should be signed. When topsoil will be stored for more than 1 year, stockpiles should 

not exceed 2 feet in depth. They should be seeded with a prescribed seed mixture and covered with mulch 

to reduce erosion and discourage weed invasion. Runoff should be diverted around topsoil stockpiles to 

minimize erosion of topsoil materials. In most cases, disturbances will be reclaimed within 1 year. 

Therefore, it is unlikely that topsoil will be required to be stockpiled for more than 1 year. Salvaged 

topsoil from roads and project sites will be respread over cut-and-fill surfaces not actively used during the 

project life. 

In some cases, there may be insufficient quantities of topsoil available for salvage to adequately cover the 

surfaces upon final reclamation and revegetation. In these cases, there is the need to find sui replacement 

or substitute growth media; this may include using subsoils or strata deeper within the overburden with 

suitable characteristics for plant growth. Deficiencies in the replacement or substitute soil could be made 

up by using soil amendments. See http://www.nps.gov/plants/restore/pubs/intronatplant/planning.htm for 

a good overview on the restoration process and soil needs. 

SITE PREPARATION 

It is important to consider diversity in seedbed preparation to account for various seed sizes and 

establishment strategies of different species. Consideration should be given for seed-safe sites, water 

infiltration and collection, shade, and frost protection. 

RECONTOURING 

Trees, shrubs, and ground cover adjacent to disturbance areas but not cleared from rights-of-way (ROW) 

require protection from construction damage. Recontouring to preconstruction condition as well as 

restoration of normal surface drainage are required. 

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APPENDIX E—RECLAMATION GUIDANCE
 

ROAD RECLAMATION GUIDELINES 

Road reclamation guidelines are as follows: 

	 Determine the desired level of obliteration and reclamation. Determine whether there are 

alternative short- or long-term uses for roads. 

	 Determine short- and long-term reclamation objectives and goals. Identify the monitoring 

methods to determine reclamation success or failure and possible mitigation. 

	 Reclaim the road; the effort may include ripping and scarifying the surface, removing culverts 

and other flow structures, recontouring cut-and-fill slopes to provide for complete removal of the 

road, and total recontouring to the original topographic profile. 

	 Reclaim vegetation to standards outlined in the section on “criteria for reclamation.” 

	 Establish mitigation measures to remedy problems identified by monitoring. 

WEEDS 

One of BLM’s highest priorities is to promote ecosystem health, and one of the larger obstacles to 

achieving this goal is the rapid expansion of weeds across public lands. Invasive plants can dominate sites 

and often cause long-term changes to native plant communities. If not eradicated or controlled, noxious 

weeds will jeopardize the success of reclamation. Invasive weeds can slow reclamation success or halt it 

altogether. ROW, mineral lease, mining claim, and permit holders are required to monitor and control 

noxious and invasive weeds on public land as stipulated within their permits and authorizations. Some 

recommended best management practices (BMP) for weed control are located in Appendix 31, Rawlins 

Field Office Noxious Weed Prevention Plan (see Proposed RMP/Final EIS). 

SEED 

On all areas to be reclaimed, seed mixtures are required to be weed free and site-specific, composed of the 

same native species as were disturbed, or early successional species consisting of pioneer species, 

including seasonal or annual species (that may only be evident at certain times of the year), that will lead 

to a similar climax community as that disturbed. Site preparation and species choices must ensure soil 

stability. 

A pre-disturbance species composition list must be developed for each site to ensure proper community 

composition, function, and structure. This will ensure that the type of vegetative community replaced is 

compatible with climate and soil types and should make it easier for the project proponent to successfully 

restore and stabilize specific sites. 

Livestock palatability and wildlife habitat needs must be given consideration in seed mix formulation 

during reclamation within areas of important wildlife habitat (crucial winter range, sage-grouse nesting 

habitat, etc.); provision shall be made for the replacement of native browse and forb species. BLM 

guidance for native seed use is the BLM Manual 1745 and Executive Order (E.O.) 13112 (Invasive 

Species, 64 Code of Federal Regulations [CFR] 6183). 

It is helpful to become familiar with the following terms when ordering seed to assist in making informed 

decisions. 

Certified Seed (Blue Tag) 

This certification only applies to seed produced through cultivation, not seed collected in the wild. The 

seed certification system promotes the production and purchase of seed of known genetic identity. Only 

cultivated, named varieties can be certified. A certification agency inspects field conditions and regulates 

how the seed is produced, harvested, and cleaned. The seed is subject to a variety of laboratory tests. This 

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APPENDIX E—RECLAMATION GUIDANCE
 

certification process guarantees the seed has the same genetic potential to perform in the field as the 

original seed did when it was released for production. 

Source Identified Seed (Yellow Tag) 

The Association of Official Seed Certifying Agencies (AOSCA) has an approved seed certification class 

for native seed collection called the “Source Identified Class.” The tag confirms to the purchaser that the 

location of seed harvest was verified by the certifying agency. 

Pure Live Seed 

Pure live seed (PLS) is a measure describing the percentage of a quantity of seed that will germinate. It is 

a way to standardize quality so the purchaser can compare the quality and value of different lots of seed. 

One lot may be cheaper but may not have as high a PLS as another lot, and therefore may not be a better 

buy because fewer seeds would actually germinate. 

PLS = percent purity * percent germination rate/100 

Example: 90 percent purity * 50 percent germination rate/100 = 45 percent PLS 

Seed Testing and Labeling 

Seed Operators should include a clear label on each bag of seed that shows the results of purity and 

germination tests and the scientific name of the species. The Association of Official Seed Analysts 

oversees these tests. Purity of the seed is the percentage of the labeled species by weight. The percentages 

of other crop, weed, inert material, and the percentage of dormant or hard seed should also be included. 

The label should also show the percentage of the seed count that will germinate 

Site Adapted Custom Seed Collection 

Some seed Operators also may offer collection services that involve harvesting seed from sites that the 

customer specifies. This is a preferred method for many who want to ensure that their seed is from local 

sources. 

Seed Suppliers 

Many of the considerations for choosing plant material suppliers also apply to choosing seed suppliers. 

Seed suppliers should operate in the same geographic ecoregion as the restoration site because that 

supplier is most likely to have native seed suitable for that area. Companies specialize in native seed 

collection, processing, and growing, and can have a wealth of knowledge about native plants and seeds. 

Do not rely on a single supplier for all seed needs. 

Standard Seed Mixtures—Rawlins Field Office 

Care and planning must be taken to choose mixes and amounts that will benefit under site-specific 

conditions. Planning and thought must also go into selecting successful planting and site-preparation 

techniques. All sites must be planted with a diverse mix of grasses, forbs, and shrubs to be considered 

successful. The project proponent is ultimately responsible for successful restoration of disturbed sites. 

Alternate seed mixes can be submitted by the project proponent to BLM for review and approval prior to 

use. The final goal is to restore disturbed sites so that they closely resemble pre-disturbance native plant 

communities. Some standard seed mixes are available for the Rawlins Field Office and contain only 

native species. If the use of a non-native species is desired, documentation of the need is required by 

BLM policy. Non-native species may be considered for erosion and weed control. Seed mixtures 

consisting of sterile annual cover crops, such as tricale hybrid, can be used. The use of a non-sterile plant 

species such as wheat as a cover crop is not recommended because of its ability to reseed itself. FollowContinental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-9 
APPENDIX E—RECLAMATION GUIDANCE
 

up seeding or corrective erosion control measures will be required on areas of surface disturbance that fail 

to meet reclamation success standards within a reasonable time. 

Mulch 

Use of mulch during reclamation may enhance chances for successful vegetation reestablishment. 

Mulches can help control wind and water erosion, retain and collect seed, increase and prolong soil water 

capacity, and add organic compounds to the soil. Mulches are best applied after seeding to ensure proper 

seed contact with soil. Mulch may include hay, small-grain straw, wood fiber, live mulch, cotton, jute, or 

synthetic netting. Straw mulch should contain fibers long enough to facilitate crimping and provide the 

greatest cover. Take care that mulch is not more than 1 inch deep; if too deep a layer is applied, it can 

retard vegetation establishment. 

Any mulch used must be certified free from mold, fungi, or noxious or invasive weed seeds. 

LIVE PLANTINGS 

Live plants can be planted on disturbed sites and, with proper site preparation, can greatly enhance 

restoration efforts and shorten time frames. Operators can buy bare root and container stock directly from 

vendors or can contract seed collection and growth from local growers. Another strategy is to use an 

excavator to collect clumps of plants from the site and plant them either on reserved topsoil piles and/or 

on restoration sites during recontouring. These clumps can provide native seed and soil flora as well as 

collect precipitation and provide shade for newly emerging plants. 

Seeding and Planting Methods 

There are many types and configurations of rangeland seeders, interseeders, and transplanters. Be sure to 

use the right tool for the job. The equipment should be set up to segregate seed by size and planting depth. 

The contractor should know when, where, and under what conditions to plant the appropriate species. 

Many forbs, shrubs, and some grasses do not compete well as young plants and should be planted with 

compatible species. Less aggressive, slower growing species should be planted separately from faster 

growing more aggressive species. Some species require companion species; there are many variables, so 

care must be taken in seed selection and planting technique. 

Most conventional grain drills are inadequate for rangeland seeding. Their seed boxes are generally not 

individually suspended, and their depth regulators are usually inadequate for native species and generally 

plant too deep. Adequate equipment and knowledge of site-specific reclamation practices is paramount to 

the success of seeding objectives. Look for contractors using proven rangeland equipment and methods. 

For example, they should have a rangeland drill, Truax drill, land imprinter, Amazon no-till drill, 

broadcast seeder, Brillion-seeder, seeder-scalper, interseeders, surface seeder, hydro-seeder, scarifier, 

dozer, or other appropriate equipment. 

Depending on site-specifics such as soil types and soil moisture, there are a number of ways to properly 

prepare seedbeds. It is best to prepare the seedbed early in the fall and then plant in late fall or early 

winter. However, when proper conditions exist, planting can occur through the winter into early spring. 

Planting at other times of the year will have higher chances for failure. Care should be taken not to work 

soils that are too wet because compaction and soil crusting can occur. 

Seedbed preparation and seeding often occur simultaneously. Therefore, it is critical to choose the proper 

methods and timing. A good strategy for seed mixes is to leave seedbeds in a rough surface condition, 

then broadcast seed, followed by light chaining or harrowing. Deep furrow drilling should not be used in 

dry soils or in loose soils because it tends to slough and leave seeds at uneven depths and often too deep 

for germination. Deep furrow drilling in tighter soils may be appropriate because it can reduce soil 

moisture loss and shade new seedlings. Cultipacker seeders, punch drills, pitting, and some compact drills 

E-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX E—RECLAMATION GUIDANCE
 

may also be a good strategy for loose soil types, particularly if they are able to segregate seed and plant at 

varying depths. 

Planting container or bare-root stock requires specific strategies that have been proven successful. Some 

methods that can be used include random hand-planting, trenching, inter-seeding, and deep-furrow 

planting. 

It is essential to consider several options for seedbed preparation to account for soil types, pH, structure, 

variable seed size, planting depths, competition, and the establishment of strategies for different species. 

Consideration should be given for seed-safe sites, water infiltration and collection, shade, and frost 

protection. 

Planning and Monitoring 

For each discrete site where ground disturbing activities are planned, a site-specific reclamation plan shall 

be prepared, submitted, and approved by BLM before the project proponent disturbs the environment. 

Guidance and requirements for this plan can be found in program-specific direction (USDI, BLM 1983). 

A project-wide reclamation plan may be considered if it addresses the individual site disturbances 

specifically. 

With the exception of active work areas, disturbed areas anticipated to be left bare and exposed will be 

stabilized with at least a 50-percent cover of mulch to prevent soil erosion. Variation of the cover 

percentage and the use of other stabilizing materials can be proposed and used with BLM approval 

consistent with the relevant project-specific reclamation plan. For areas anticipated for further disturbance 

in the near future, use of the seed mixtures detailed in Temporary Seed Mixtures may be acceptable in the 

interim. 

First Growing Season 

Reclamation actions will be implemented before the first growing season following disturbance with the 

goal of returning the land to a condition approximate to or more productive than that which existed before 

disturbance or to a stable and productive condition compatible with that described in the land use plan 

Consistent with the reclamation plan, the operator will ensure the following during the first growing 

season. 

Prior to the beginning of the growing season— 

 Stabilize disturbed site soils until they are revegetated with no obstacles to germination and 

growth of seed 

 Properly prepare the site by— 

o	 Recontouring for permanent reclamation 

o	 Completing soil preparation activities, such as ripping, straw crimping/seedbed preparation 

for planting, including drilling and broadcast methods 

o	 Planting the approved seedling/seed mixtures using site-specific methods for successful 

revegetation using regionally, and/or site-adapted genotypes 

o Ensuring that weed treatments are compatible with seed mixtures. 

During the first growing season— 

	 Monitor germination and growth of plants in the area being reclaimed 

	 Detect and control weeds in all areas―not just reclaimed areas 

	 Use adaptive management to correct establishment and growth problems 

	 Put up temporary fencing to avoid adverse effects to reclamation 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-11 
 

APPENDIX E—RECLAMATION GUIDANCE
 

 Build snow fencing, if requested, to increase effective precipitation and regenerate vegetation. 

Following each growing season— 

 Review and complete a site-specific vegetation monitoring report for areas being reclaimed 

(Table A36-1) 

 Prepare a written, site-specific prescription for actions to be implemented, including— 

o	 Reseeding of areas not attaining reclamation success 

o	 Soil stabilization 

o	 Weed control needs 

o	 Mulching/fertilization or other cultural practices prescribed for the following season. 

If the treatment area is found, through site-specific monitoring data, to be successfully reclaimed, 

monitoring to confirm reclamation success will continue for at least five seasons. The site will also 

comply with additional management needs, including control of weed infestations. 

If the reclamation area is not successfully reclaimed or otherwise requires further management activities 

to establish vegetation, the actions prescribed will be implemented as planned and further monitoring will 

occur as detailed beginning with the first action listed above. 

PROJECT PROPONENT RECLAMATION MONITORING REPORTS 

The project proponent will provide BLM with an annual report before December 1 for all sites disturbed. 

The report will include— 

	 Copies of the completed individual site review forms or a BLM-approved electronic report 

	 A summary of monitoring data and results, including— 

o	 Individual site reclamation monitoring reporting data (Table A36-1) 

o	 Identification of sites successfully reclaimed by reclamation years (starting with the first 

growing season) 

o	 Identification of sites needing additional work or more reclamation activities by reclamation 

year 

o	 Sites proposed for the end of monitoring (i.e., sites that were successfully reclaimed) 

	 BLM useable shape file(s) or geographic information system (GIS) layer(s) that details location, 

name, type, and extent of— 

o	 New disturbances 

o	 Unreclaimed disturbance 

o	 New reclamation 

o	 Failed or unsuccessful reclamation 

o	 Locations of noxious/invasive weed infestation 

o	 Further vegetation treatments planned (e.g., mulching, matting, and weed control). 

On these shape files or GIS layers, location shall be given as the legal location and geo-referenced 

location of the site; name, as appears on the BLM Application for Permit to Drill (APD), lease, or other 

BLM file name for the site; and extent, as the amount of area and location of the item. 

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APPENDIX E—RECLAMATION GUIDANCE
 

CRITERIA FOR RECLAMATION SUCCESS 

Criteria based on pre-disturbance surveys or surveys of adjacent undisturbed natural ground cover and 

species composition 2 or— 

 Eighty percent of pre-disturbance ground cover 

 Ninety percent dominant species 

 No noxious weeds 

 Erosion features equal to or less than surrounding area. 

Monitoring results must be from a standardized cover/species protocol finalized by BLM. 

Table A36-1. Reclamation Monitoring Reporting Data 

General 

WYW# (Oil and Gas Lease or ROW) 

Project Name 

Project Type (Well, Access Road, Pipeline, Facility, etc.) 

Qtr/Qtr Sec, T, R, County, State 

Disturbance Disturbance Dates 

Start-End 

Reclamation Type (Interim/Final) 

Earthwork Contractor Name 

Reclamation Earthwork & Topsoil Completion Date 

Soil Preparation Ripping Depth 

Area (Acres or Square Feet) 

Seeding Contractor Name 

Seeding Date 

Seedbed Preparation Methods (Disc, Harrow, Depths) 

Seeding Seeding Method (Drill, Broadcast, Depths) 

Copy of Seed Tag (Species percent, Purity percent, Germination percent) 

Actual Seeding Rate (Lbs/Acre) 

Area Seeded (Acres or Square Feet) 

Soil Amendments Used (Describe) 

Other Mulching/Erosion Netting/Tackifier 

Fenced Location 

Snow Fencing 

Type(s) of Weed Treated 

Weed Contractor Name 

Contractor License # 

Weeds Weed Treatment Date 

Weed Treatment Type (Chemical, Mechanical) 

Chemicals Used and Rates Applied 

Area Treated (Acres or Square Feet) (GIS Extent and Location) 

The vegetation will consist of species included in the seed mix and/or occurring in the surrounding natural vegetation or as 

deemed desirable by BLM in review and approval of the reclamation plan. No single species will account for more than 30 

percent total vegetative composition unless it is evident at higher levels in the adjacent landscape. Vegetation canopy cover 

production and species diversity shall approximate the surrounding undisturbed area 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-13 

2 
 

APPENDIX E—RECLAMATION GUIDANCE
 

Table A36-1. Reclamation Monitoring Reporting Data, continued 

Inspection 

Inspector’s Name, Company, ID 

Inspection Date 

Time After Seeding 

Seedlings/Square Feet Growing

 percent and Extent of Bare Soil

 percent Ground Cover (Describe)

 percent Desirable Species (Describe) 

percent Noxious/Invasive Weeds (Describe) 

Erosion Features Present? (Describe) 

Evidence of Livestock Grazing (Describe) 

Reclamation Successful (Yes/No) 

Completed Spreadsheet or Database 

Reporting GIS Layer with Attribute Table with Site Data as Detailed 

Detail Disturbance Extent and Location 

Permanent Reference Point 

Monitoring Reference Photos 

Close-up Photos 

Reseeding 

Future Management 

Prescription 

Weed Control Needed 

Erosion Control Needed 

Grazing/Predation Issues 

Other Cultural or Mechanical Issues 

E-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX E—RECLAMATION GUIDANCE
 

United States Department of the Interior

BUREAU OF LAND MANAGEMENT
 

High Desert District
 

280 Highway 191 North
 

Rock Springs, Wyoming 82901
 

2800, 3100, 

3200, 3400, 

3500, 3600, 

3700, 3800 (WYD00) 

 May 30, 2012 

Instruction Memorandum No. WYD 2012-005 

Expires: 09/30/2016 

To: Field Managers, High Desert District 

From: District Manager, High Desert 

Subject: High Desert District Policy for Reclamation of Disturbed Lands 

Program Area: All Surface Disturbing Activities. 

Purpose: To affirm and adopt the Wyoming Reclamation Policy as codified in Instruction 

Memorandum WY-2012-032, dated March 27, 2012. 

Policy/Action: In order to ensure a consistent and science-based approach to reclamation, the 

High Desert District (HDD) is adopting and implementing Instruction Memorandum (IM) WY2012-032 with its ten reclamation requirements as the minimum standards that must be 

addressed when developing reclamation proposals for all surface disturbing activities occurring 

within the HDD. Addressing these ten requirements will help achieve both short and long-term 

reclamation success for site stabilization and eventual ecosystem reconstruction, as well as 

promoting reclamation planning and implementation consistency within and across the Field 

Office boundaries. 

IM WY-2012-032 is supported with more detailed guidance such as a statewide monitoring and 

reporting strategy, and sample templates, and other technical guidance posted on the Wyoming 

Reclamation web site (http://www.blm.gov/wy/st/eniprograms/reclamation.html). 

Timeframe: This IM is effective immediately. 

Budget Impact: None 

Background: Successful reclamation efforts are critical in maintaining an effective multiple use 

land management program. Nearly all authorizations for surface disturbing actions are based 

upon the assumption that an area can and ultimately will be successfully reclaimed. Those 

seeking approval to conduct surface disturbing activities on Public Lands must include 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-15 
APPENDIX E—RECLAMATION GUIDANCE
 

reclamation planning as part of their permit process and the BLM must make this requirement 

clear early in the permitting process. This IM applies to all BLM authorized surface disturbing 

actions occurring within the High Desert District including those initiated by the BLM. 

While development of a reclamation plan is a crucial component to achieving a successful 

reclamation project, it can also become an overwhelming and overly-burdensome process for 

operators, lessees, permit holders, and grant holders, as well as for BLM. It is imperative for us 

to remember that the overriding objective is to achieve successful restoration/reclamation of 

the disturbed area. It is far more desirable to have our external customers (lessees, operators, and 

grant holders, etc.), as well as BLM concentrate the bulk of their and our reclamation dollars on 

the physical on-the-ground reclamation components of the project, rather than on the 

development of the plan. To that end it is imperative that we require the reclamation plans to 

include no more than the minimum level of predisturbance site data and project component 

description than is essential to assure the plan will meet the reclamation objective for the site. In 

reiteration, do not require operators, lessees, and/or grant holders to gather and provide 

more information than is necessary to verify that their reclamation plan will accomplish 

BLM's interim and final reclamation objectives for the site. Remember that all BLM 

initiated surface disturbance activities occurring within the District are also fully bound by this 

policy; therefore our internal reclamation plans and pre-disturbance data gathering requirements 

must be every bit as detailed as those we are requiring from our external customers. 

A "hand-in-hand" component with reclamation planning is post-reclamation monitoring. 

Without effective monitoring we cannot document whether the reclamation project is successful 

or not, whether it meets the planned objective or not, nor will be we have a starting point from 

which to initiate corrective measures. Effective monitoring will involve both the operators and 

BLM. Refer to Section 10 of the Wyoming Reclamation Policy. 

Existing field office reclamation policies must be reviewed and modified as necessary to insure 

that they comply with requirements of this 1M and with the BLM Wyoming Reclamation Policy 

WY-2012-032). 

E-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

APPENDIX E—RECLAMATION GUIDANCE
 

In reply refer to: 

3042 (921Gamper) P 

March 27, 2012 

EMS TRANSMISSION: 4/2/2012 

Instruction Memorandum No. WY-2012-032 

Expires: 9/30/2013 

To: District Managers and Deputy State Directors 

From: Associate State Director 

Subject: Wyoming Bureau of Land Management (BLM) Reclamation Policy 

Program Areas: All Surface Disturbing Activities. 

Purpose: Implement the Wyoming Reclamation Policy 

Policy/Action: In order to ensure a consistent and science-based approach to reclamation, this 

Instruction Memorandum (IM) identifies ten reclamation requirements (see Attachments) that must 

be addressed when developing reclamation proposals for all surface disturbing activities. Addressing 

these ten requirements will help achieve both short and long-term reclamation success for site 

stabilization and eventual ecosystem reconstruction. The Wyoming Reclamation Policy was 

previously issued under IM No. WY-2009-022 which expired on September 30, 2010. This IM 

replaces IM No. WY-2009-022. 

Background: Successful reclamation efforts are critical in maintaining an effective multiple-use land 

management program. Nearly all authorizations for surface disturbing actions are based upon the 

assumption that an area can and ultimately will be successfully reclaimed. Those seeking approval to 

conduct surface disturbing activities on Public Lands must include reclamation planning as part of 

their permit process and the BLM must make this requirement clear early in the permitting process. 

This IM applies to all BLM authorized actions including those initiated by the BLM. 

Timeframe: Effective immediately. 

Budget Impact: Savings to Project funds in the long-term. 

Manual/Handbook Sections Affected: This IM will be supported with more detailed guidance 

including new reclamation bond standards and a statewide monitoring and reporting strategy. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-17 
 

 

 

 

 

APPENDIX E—RECLAMATION GUIDANCE
 

Specific reclamation information, sample templates for both reclamation and weed management 

plans, and other technical guidance is posted on the Wyoming Reclamation web site 

(http://www.blm.gov/wy/st/en/programs/reclamation.html). 

Coordination: The coordination and review of the Wyoming Reclamation Policy has been 

completed with the WY BLM Reclamation Team: Brenda Neuman, Mining Engineer, WSO; Ken 

Henke, Natural Resource Specialist, WSO; Adrienne Pilmanis, Botanist, WSO; Travis Bargsten, 

Physical Scientist, WSO; and Merry Gamper, Physical Scientist, WSO Lead. Other non-Wyoming 

BLM specialists, WO-310, the Wyoming Governor’s Office (for review by all appropriate State 

Agencies), the University of Wyoming, some local Governments, and numerous interested 

reclamation professionals in private industry statewide. 

Contact: Merry Gamper at 307-775-6272, and by e-mail at MGamper@BLM.gov. 

Signed By: Authenticated By: 

Ruth Welch Sherry Dixon 

Associate State Director Secretary 

2 Attachments 

1 - Wyoming BLM Reclamation Policy (6 pp) 

2 - Wyoming BLM Oil and Gas Reclamation Plan Template (4 pp) 

Distribution 

Director (200), Rm. 5644, MIB 1 1 (w/o atch) 

Director (300), Rm. 5625, MIB 1 1 (w/o atch) 

Field Managers 1 (w/atch) 

CF 1 (w/atch) 
 

E-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX E—RECLAMATION GUIDANCE
 

Wyoming Reclamation Policy 

The Wyoming Reclamation Policy is guidance for the modification, preparation and/or review of all 

reclamation plans. It applies to all Federal actions authorized, conducted, or funded by the BLM that 

disturb vegetation and/or the mineral/soil resources. This policy is intended to be support all BLM 

program objectives. 

A reclamation plan shall be developed for all surface disturbing activities and will become part of the 

proposed action in the NEPA document. The level of detail for the reclamation plan shall reflect: the 

complexity of the project, the environmental concerns, the reclamation potential for the site, and the revegetation strategy. These plans shall also incorporate any program or regulatory specific requirements 

for reclamation. The reclamation plan shall address short term stabilization to facilitate long term 

reclamation. The reclamation plan is considered complete when all the reclamation requirements 

described below have been addressed, the techniques to meet the reclamation requirements are described 

in detail, and the BLM concurs with the reclamation plan. 

Many landscapes can be reclaimed using established conventional reclamation methods. However, some 

areas have unique characteristics that make achieving all the reclamation requirements described in this 

policy unrealistic. Innovative techniques beyond conventional practices must be considered and applied to 

reclaim these more challenging areas. Areas posing the most extreme reclamation challenges will be 

identified as having Limited Reclamation Potential (LRP). These areas are often characterized by highly 

sensitive and/or erosive soils, highly sensitive vegetation types, soils with severe physical or chemical 

limitations, extremely steep slopes, etc. These LRP areas may require site-specific reclamation measures 

not specifically addressed in the Wyoming Reclamation Policy. Each Field Office shall develop a unique 

set of reclamation success requirements for those areas within the framework of the attached Policy. The 

additional difficulty of reclaiming these LRP areas should be considered in the Resource Management 

Plan and evaluated when planning surface-disturbing activities. During the NEPA process, alternatives to 

approving development activities in LRP areas should be carefully analyzed. Alternatives considered 

should include: avoidance and/or unconventional site specific reclamation requirements. Resource 

development activities approved in these areas may require additional bonding. 

A. RECLAMATION GOALS 

1.	 Short term goal: immediately stabilize disturbed areas and provide conditions necessary to 

achieve the long term goal. 

2.	 Long term goal: facilitate eventual native plant community and ecosystem reconstruction to 

maintain a safe and stable landscape and meet the desired outcomes of the land use plan. 

B. RECLAMATION REQUIREMENTS 

The following Reclamation Requirements apply to all surface disturbing activities, including BLM 

initiated activities, and must be addressed in each reclamation plan. These requirements also must be met 

prior to release of the bond and/or the reclamation liability. Where these Reclamation Requirements 

differ from other applicable Federal laws, rules, and regulations, those requirements supersede this 

policy. State and/or local statutes or regulations may also apply. 

1. Manage all waste materials: 

a.	 Segregate, treat, and/or bio-remediate contaminated soil material. 

b.	 Bury only authorized waste materials on site. Buried material must be covered with a minimum 

of three feet of suitable material or meet other program standards. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-19 
 

APPENDIX E—RECLAMATION GUIDANCE
 

c. Ensure all waste materials moved off-site are transported to an authorized disposal facility. 

2.	 Ensure subsurface integrity, and eliminate sources of ground and surface water contamination. 

a.	 Properly plug all drill holes and other subsurface openings (mine shafts, adits etc.). 

b.	 Stabilize, properly back fill, cap, and/or restrict from entry all open shafts, underground workings, 

and other openings. 

c.	 Control sources of contamination and implement best management practices to protect surface 

and ground water quality. 

3. Re-establish slope stability, surface stability, and desired topographic diversity. 

a.	 Reconstruct the landscape to the approximate original contour or consistent with the land use 

plan. 

b.	 Maximize geomorphic stability and topographic diversity of the reclaimed topography. 

c.	 Eliminate highwalls, cut slopes, and/or topographic depressions on site, unless otherwise 

approved. 

d.	 Minimize sheet and rill erosion on/or adjacent to the reclaimed area. There shall be no evidence 

of mass wasting, head cutting, large rills or gullies, down cutting in drainages, or overall slope 

instability on/or adjacent to the reclaimed area. 

4. Reconstruct and stabilize water courses and drainage features. 

a.	 Reconstruct drainage basins and reclaim impoundments to maintain the drainage pattern, profile, 

and dimension to approximate the natural features found in nearby naturally functioning basins. 

b.	 Reconstruct and stabilize stream channels, drainages, and impoundments to exhibit similar 

hydrologic characteristics found in stable naturally functioning systems. 

5. Maintain the biological, chemical, and physical integrity of the topsoil and subsoil (where 

appropriate). 

a.	 Identify, delineate, and segregate all salvaged topsoil and subsoil based on a site specific soil 

evaluation, including depth, chemical, and physical characteristics. 

b.	 Protect all stored soil material from erosion, degradation, and contamination. 

c.	 Incorporate stored soil material into the disturbed landscape. 

d.	 Soil storage piles to be stored beyond one growing season, should be seeded with appropriate 

vegetation (native or sterile non-native species). 

e.	 Identify stockpiles with appropriate signage. 

6. Prepare site for revegetation. 

a.	 Redistribute soil materials in a manner similar to the original vertical profile. 

b.	 Reduce compaction to an appropriate depth (generally below the root zone) prior to redistribution 

of topsoil, to accommodate desired plant species. 

c.	 Provide suitable surface and subsurface physical, chemical, and biological properties to support 

the long term establishment and viability of the desired plant community. 

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APPENDIX E—RECLAMATION GUIDANCE
 

d.	 Protect seed and seedling establishment (e.g. erosion control matting, mulching, hydro-seeding, 

surface roughening, fencing, etc.) 

7. Establish desired self-perpetuating native plant community. 

a.	 Establish species composition, diversity, structure, and total ground cover appropriate for the 

desired plant community. 

b.	 Enhance critical resource values (e.g. wildlife, range, recreation, biodiversity, etc.), where 

appropriate, by augmenting or accelerating restoration of plant community composition, 

diversity, and/or structure. 

c.	 Select genetically appropriate and locally adapted native plant materials (e.g. locally sourced or 

cultivars recommended for seed zone) based on the site characteristics and ecological setting. 

d.	 Use locally sourced and/or collected seeds to the extent possible (local collection and logistics 

should be included in the Reclamation Plan). 

e.	 Select non-native plants only as an approved short term and non-persistent (i.e. sterile) alternative 

to native plant materials. Ensure the non-natives will not hybridize, displace, or offer long-term 

competition to the endemic plants, and are designed to aid in the re-establishment of native plant 

communities. 

8.	 Reestablish a complementary visual composition 

a.	 Ensure the reclaimed landscape features blend into the adjacent area and conform to the land use 

plan decisions. 

b.	 Ensure the reclaimed landscape does not result in a long term change to the scenic quality of the 

area. 

9. Manage Invasive Plants 

a.	 Assess for invasive plants before initiating surface disturbing activities. 

b.	 Develop an invasive plant management plan. 

c.	 Control invasive plants utilizing an integrated pest management approach. 

d.	 Monitor invasive plant treatments. 

10. Develop and implement a reclamation monitoring and reporting strategy. 

a.	 Conduct compliance and effectiveness monitoring in accordance with a BLM (or other surface 

management agency) approved monitoring protocol. 

b.	 Evaluate monitoring data for compliance with the reclamation plan. 

c.	 Document and report monitoring data and recommend revised reclamation strategies. 

d.	 Implement revised reclamation strategies as needed. 

e.	 Repeat the process of monitoring, evaluating, documenting/reporting, and implementing, 

until reclamation goals are achieved. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-21 
 

APPENDIX E—RECLAMATION GUIDANCE
 

GLOSSARY 

Contamination - The presence of man-made chemicals or other alterations in the natural soil or 

water environment (pesticides, hazardous substances, petroleum, salts). 

Adapted from various sources 

Desired Outcome: Specific goal/objectives and allowed uses outlined in land use plans. Desired 

outcomes should be identified for and pertain to resources (such as natural, biological, and cultural), 

resource uses, (such as energy and livestock grazing), and other factors (such as social and economic 

conditions). 

BLM Handbook H-1601-1 

Ecosystem - Includes all the organisms of an area, their environment, and the linkages or interactions 

among all of them; all parts of an ecosystem are interrelated. The fundamental unit in ecology, 

containing both organisms and abiotic environments, each influencing the properties of the other and 

both necessary for the maintenance of life. 

Vegetation Treatments Using Herbicides in 17 Western States, Programmatic Environmental Impact 

Statement (BLM 2007) 

Federal Action - Approval of specific projects, such as construction or management activities 

located in a defined geographic area. Projects include actions approved by permit or other regulatory 

decision as well as federal and federally assisted activities. 

National Environmental Policy Act (NEPA) [42 U.S.C. 4321 et seq.] 

Invasive Plant - A species that is not native (or is alien) to the ecosystem under consideration and 

whose introduction causes or is likely to cause economic or environmental harm or harm to human 

health. Plants listed on the State of Wyoming, Designated Noxious Weed List, would be included 

under this definition. 

Executive Order 13112, Invasive Species (1999) 

Limited Reclamation Potential (LRP) - Areas possessing unique landscape characteristics (e.g., sensitive 

geologic formations, extremely limiting soil conditions, biological soil crusts, badlands, rock-outcrops, 

etc.) often make reclamation success impractical and/or unrealistic due to physical, biological, and/or 

chemical challenges. When disturbed, these areas may require unconventional reclamation strategies to 

address the ten requirements established by this Policy. 

Adapted from various sources 

Locally-sourced native plant materials - seeds, seedlings, transplants, and/or inocula obtained and/or 

increased from collection at the project location or from nearby similar sites. 

Adapted from various sources including the Integrated Vegetation Management Handbook 1740-2, Ch. 8, 

and Johnson et al 2010 “What Are The Best Seed Sources For Ecosystem Restoration on BLM and USFS 

Lands?”, Native Plants, 11:2:117-131 

Reclamation Plan – The Reclamation Plan is a written document that addresses the reconstruction of 

disturbed ecosystems by returning the land to a stable and productive condition compatible with the 

land use plan. The Plan must address all ten requirements included in this Policy. 

Adapted from various sources 

E-22 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX E—RECLAMATION GUIDANCE
 

Scenic Quality – The overall impression of a landscape retained after driving or walking through, or 

flying over an area. The Scenic Quality of an area is rated as Class A (outstanding visual 

characteristics), Class B (combination of outstanding and common visual characteristics), and Class 

C (common visual characteristics). See BLM Handbook H-8410 Visual Resource Inventory and BLM 

Handbook H-8431 Visual Resource Contrast Rating. 

Soil – A natural, three-dimensional body at the earth’s surface. It is capable of supporting plants and 

has properties resulting from the integrated effect of climate and living matter acting on earthly 

parent material, as conditioned by relief over periods of time. 

Glossary of Soil Science Terms 

Subsoil – Technically, the subsoil includes the B horizon. This is roughly, the part of the solum 

below the organic topsoil and above the rocky parent material of the C horizon. When suitable, the 

subsoil may be salvaged to supplement the topsoil for plant establishment. 

Adapted from various sources 

Soil Material – Includes the topsoil and/or the topsoil and a portion of the subsoil salvaged and 

separated to be used to provide a growth medium for plant establishment. 

Adapted from various sources 

Surface Disturbing Activities – An action that alters the vegetation, surface/near surface soil 

resources, and/or surface geologic features, beyond natural site conditions and on a scale that affects 

other Public Land values. Examples of surface disturbing activities may include: operation of heavy 

equipment to construct well pads, roads, pits and reservoirs; installation of pipelines and power lines; 

and the conduct of several types of vegetation treatments (e.g., prescribed fire, etc.). Surface 

disturbing activities may be either authorized or prohibited. 

Wyoming Information Bulletin 2007-029, Guidance for Use of Standardized Surface Use Definitions 

Surface Management Agency –Any Federal or State agency having jurisdiction over the surface 

estate. Adapted from Onshore Oil and Gas Order No. 1 

Topsoil – The biologically active, upper part of the soil profile, being the most favorable material for 

plant growth. 

Adapted from U.S.D.A., Natural Resources Conservation Service 

Waste materials – Any discarded or abandoned material that can interfere with successful 

reclamation, safety, and long term stability of a site (contaminated soil or water, drilling mud, solid 

waste). 

Adapted from various sources 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-23 
 

 

APPENDIX E—RECLAMATION GUIDANCE
 

Proposed Interim Rollover Objective for the 

Continental Divide-Creston Natural Gas Project 

Environmental Impact Statement and Record of Decision 

February 25, 2011 

Table of Contents 

CD-C Reclamation Goal Statements....................................................................................................... E-27 

A.	 Pre-planning and inventory ........................................................................................................ E-27 

1.	 Identify landscape features and climate .............................................................................. E-27 

2.	 Suitable soil inventory ......................................................................................................... E-28 

3.	 Vegetation inventory ........................................................................................................... E-28 

4.	 Select a reference area......................................................................................................... E-29 

B.	 Invasive plant management plan for construction and reclamation activities ........................... E-29 

C.	 Develop a reclamation plan ....................................................................................................... E-29 

1.	 Identify and address any vegetation, climate, landscape or soil issues found 

in the pre-disturbance inventory .......................................................................................... E-29 

2.	 Site preparation, storm water, surface stability and soil management for 

interim reclamation .............................................................................................................. E-29 

3.	 Describe soil amendments ................................................................................................... E-31
 

4.	 Describe Seeding methods .................................................................................................. E-31 

5.	 Seed mixes ........................................................................................................................... E-31 

6.	 Describe if and how irrigation techniques will be used in the reclamation 

plan ...................................................................................................................................... E-32 

7.	 Describe best management practices ................................................................................... E-32 

8.	 Description of monitoring and reporting protocols for reclamation rollover...................... E-32 

D.	 Indicators for successful achievement for the Interim Reclamation Objectives 

(IRO) resulting in reclamation rollover ..................................................................................... E-33 

1.	 Beginning monitoring .......................................................................................................... E-33 

2.	 Irrigation and Monitoring .................................................................................................... E-33 

3.	 Monitoring results must be from a standardized cover/species protocol 

finalized by BLM. ........................................................................................................ E-33 

4.	 Invasive weeds .................................................................................................................... E-33 

5.	 Undesirable/annual plants ................................................................................................... E-33 

6.	 Vegetation trends................................................................................................................. E-33 

7.	 Erosion ................................................................................................................................ E-33 

E.	 The monitoring data reporting required of the Operator as specified in the 

Rawlins Resource Management Plan (RMP) ............................................................................ E-33 

Appendix A. 

A. Suggestions on Stockpiling Suitable and Unsuitable Soils to Maintain Soil 

Quality................................................................................................................................. E-36 

B. Suggestions on Supplemental Irrigation .............................................................................. E-36 

C. Suggestions on Vegetation and Soil Monitoring ................................................................. E-37 

D. Web Links ........................................................................................................................... E-38 

E. List of Participants............................................................................................................... E-41 

This page blank for 2-sided copying
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-25 
 

APPENDIX E—RECLAMATION GUIDANCE
 

PROPOSED INTERIM ROLLOVER OBJECTIVE FOR THE CONTINENTAL DIVIDECRESTON NATURAL GAS PROJECT ENVIRONMENTAL IMPACT STATEMENT AND 

RECORD OF DECISION 

There were numerous industry/state agency conversations concerning some type of phased or 

consolidated development for the Continental Divide-Creston (CD-C) Environmental Impact Statement 

(EIS). Unfortunately the complexity of the lease pattern and the number of leases made this effort 

extremely challenging. Conversations led to trying to create language for authorizations, waivers, 

modifications and exceptions to the Bureau of Land Management (BLM) Rawlins Resource Management 

Plan (RMP) to provide rollover criteria that would contain more flexibility for industry, while maintaining 

healthy, desirable vegetation within the field. 

An ad hoc group came together to see if such an opportunity for additional rollover criteria might exist. 

The following outlines the framework for the discussion: 

1.	 Provide a scientifically sound framework to minimize initial disturbance and return disturbed 

areas as quickly and effectively as possible to an ecologically stable or to pre-disturbance 

condition(s). 

2.	 Identify important interim reclamation practices that are required to ensure initial and continuing 

interim rollover objectives (IRO). 

The group is recommending that the rollover criteria as outlined below be considered as an alternative to 

the current RMP rollover criteria, provided that all the pre and post disturbance activities as outlined in 

Sections A through D are implemented. 

Proposed IRO reclamation rollover criteria 

The current Rawlins RMP Criteria for Reclamation Success are based in part on pre-disturbance surveys 

or surveys of adjacent undisturbed natural ground cover and species composition or eighty percent of predisturbance ground cover and ninety percent dominant species. 

Notwithstanding the provisions of the RMP, it is our recommendation to provide an alternative to the 

above language and have revegetation cover be 70 percent of reference area cover to meet interim 

reclamation criteria. All of this 70 percent must be desirable perennial species as represented by the seed 

mix or background species. Items A, B, C, and D would also need to be completed as part of the interim 

reclamation criteria. 

The group understands that the BLM will require a comprehensive reclamation and weed management 

plan within the CD-C project boundary as well as site-specific reclamation plans. It is understood that 

many of the items we are recommending may appear duplicative to the existing Wyoming BLM 

Reclamation Instructional Memorandum or other Field Office reclamation policy. As part of the more 

flexible rollover criteria outlined below, we recommend that many of these duplicative practices should 

be required as part of the rollover criteria and not be optional. 

A. PRE-PLANNING AND INVENTORY 

Pre-disturbance inventories are used for two main purposes. The first purpose is to use site-specific 

information (soil inventory and species identification) to develop a site-specific reclamation plan. The 

second purpose is to identify any issues, such as saline soils, steep topography, or invasive species that 

will impact successful interim and/or final reclamation. Below are the elements that should be required 

for a more flexible rollover criteria. 

1.	 Identify significant landscape features and climate issues 

a.	 Climate and physical characteristics of the site are important factors to consider in 

development of a reclamation plan, particularly in identifying possible problems. For 

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APPENDIX E—RECLAMATION GUIDANCE
 

example, a site on a south-facing slope may indicate that more drought tolerant plants 

should be selected than if the site is on a north-facing slope. Topography (slope and 

aspect), climate (including postulated microclimate), and parent materials (geological 

substrates) are additional considerations in site selection and reclamation plan 

development. 

b.	 Steep topography: Steep slopes greater than 25 percent would often result in site 

instability and should be avoided. 

c.	 Poor or erodible parent materials, or a rocky surface, or marine shales, clay/siltstone, or 

selenium-bearing geological substrates at the surface may result in difficult reclamation 

conditions. Identification of these areas might indicate the need for additional site 

planning. 

2.	 Conduct a suitable soil inventory 

a.	 Soil characteristics strongly influence reclamation efforts. Fundamental characterization 

of soils ahead of disturbance can identify potential problems, so they can be addressed 

during disturbance, soil stockpiling and reclamation. 

b.	 The phrase “suitable soil” is used herein mainly because of confusion over the definition 

of topsoil. Soil depth, pH, electrical conductivity, texture, surface features (e.g. barren, 

rocky, crusty, plant litter), and organic matter content are characteristics that may be used 

to determine if a soil is suitable. Other information may be needed. See “Successful 

restoration of severely disturbed lands: Overview of critical components,” B-1202, (and 

available for free at http://ces.uwyo.edu/PUBS/B1202.pdf). 

c.	 Soil characteristics that may signal reclamation problems include: pH, electrical 

conductivity, soil texture, surface/subsurface features, sodium adsorption ratio, and soil 

compaction. These are detailed below and will be addressed by the Operator in the sitespecific reclamation plan in the APD (application to drill) approved by the BLM: 

i.	 Soils with pH 8.4 and higher. 

ii.	 Depth: No suitable soil available or very shallow, less than 75 mm (3 inches). 

iii.	 Soil solutions with an electrical conductivity greater than eight (8) dS/m. 

iv.	 Sodium Adsorption Ratio (SAR) of 13 or higher when pH is greater than 8.4 and EC 

is greater than 4.0ds/m. 

v.	 Soils having textures of clay, sand or loamy sand. 

vi.	 Surface and subsurface soil in and through the root zone dominated by coarse 

material greater than 2 mm in diameter and greater than 40 percent in the soil 

profile. 

3. Conduct a vegetation inventory 

a.	 Gathering vegetation data before a site has been cleared for drilling documents predisturbance site conditions and in turn guides reclamation decisions. 

Seed mixes should be based on desired vegetation that has historically grown on-site and 

return of cover should be gauged by comparison with actual pre-disturbance site 

conditions and/or reference areas. 

b.	 The following vegetation characteristics can signal a high probability of reclamation 

problems: 

i.	 The presence of Halophytes: e.g. Saltbush 

ii.	 The presence of Alkali Halophytes: e.g. Greasewood, Halogeton 

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APPENDIX E—RECLAMATION GUIDANCE
 

iii. The presence of noxious or invasive species: e.g. Cheatgrass, Russian thistle, 

Russian knapweed, Alyssum, Canadian thistle. 

c.	 The methodologies to be used to determine the information for the vegetation inventory 

are as follows: 

BLM guidelines for vegetation sampling: Sampling Vegetation Attributes, Interagency 

Technical Reference (1996) Revised in 1997 and 1999. BLM/RS/ST-96/002+1730. 171 

pages. URL for Sampling Vegetation Attributes: 

http://www.blm.gov/nstc/library/pdf/samplveg.pdf. All BLM technical references: 

http://www.blm.gov/nstc/library/techref.htm. 

4.	 Select a reference site 

a.	 A reference site is a land unit which is representative, in terms of physiography, soils, 

vegetation and land use history, of an area to be disturbed. Reclaimed sites are compared 

to reference sites to determine successful interim and final reclamation. 

b.	 In Wyoming, a site may be composed of multiple ecological communities (e.g. dunes, 

alkali flats, and sagebrush). Ecological variation at a given site can make it difficult to 

evaluate which adjacent area should serve as a reference. A reference site should be 

chosen based upon the pre-disturbance assessment and the identified dominant 

community on the site. This measure ensures that initial efforts to establish vegetation 

are consistent with species that naturally occur at that location. A reference site located 

adjacent to the site to be disturbed, with similar soils, vegetation, and aspect of the site 

to be disturbed should be chosen. 

B. DEVELOP A SITE-SPECIFIC INVASIVE/NOXIOUS (INVASIVE) PLANT MANAGEMENT 

PLAN FOR CONSTRUCTION AND RECLAMATION ACTIVITIES: 

Disturbed sites can provide ideal opportunities for invasive plant species to propagate. An integrated sitespecific invasive plant management plan should be developed. The plan should include: 

1.	 Assessment activities for invasive plant species before initiating surface disturbing activities 

(pre-disturbance), during disturbance (annual monitoring), during interim and final reclamation, 

and after reclamation is completed. 

2.	 Describe treatments to control invasive plants. 

3.	 Monitor invasive plant species at least annually to evaluate success of invasive plant control 

treatments and determine if continued invasive plant control is necessary. 

C. DEVELOP A SITE-SPECIFIC RECLAMATION PLAN: 

Reclamation planning provides a detailed strategy for returning a disturbed site back to a functioning predisturbance condition. The site-specific reclamation plan will be made part of the APD by the Operator 

and BLM and includes the following: 

1.	 Identify and address any vegetation, climate, landscape or soil issues found in the predisturbance inventory. 

2. Site preparation, storm water, surface stability, and soil management for interim 

reclamation. 

Site preparation activities ready a site for revegetation activities and in general include 

replacement of stockpiled suitable and unsuitable soils, reestablishing a stable subsurface 

environment, recontouring (reconstruction of landscape), incorporation of soil amendments 

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APPENDIX E—RECLAMATION GUIDANCE
 

and primary tillage/ripping to relieve soil compaction prior to spreading suitable soil and 

secondary tillage. 

a.	 Proper soil management prevents loss from erosion and preserves its ability to support a 

productive plant community, the soil biota and their habitat as well as its physical and 

chemical properties. 

b.	 The Storm Water Pollution Prevention Plan (SWPPP) as required by Department of 

Environmental Quality (DEQ) should be followed. 

c.	 Surface Stability: The following describes considerations for how the Operator could 

achieve surface stability: 

i.	 Redistribute soil materials in a manner to optimize revegetation potential. 

ii.	 Relieve compaction of the redistributed soil (suitable and unsuitable) to an 

appropriate depth just prior to seeding to accommodate desired plant species 

germination and sustained growth. 

iii.	 Preparation of the seedbed includes but not limited to: 

a.	 Seedbed preparation methods should establish surface conditions to enhance 

development of diverse, stable, and self-generating vegetation. The methods 

selected should optimize surface stability and surface roughness using 

techniques such as furrowing on the contour or surface pitting. 

b.	 Re-establish slope stability and surface stability. 

c.	 Reconstruct the landscape to the approximate original contour or a contour 

consistent with the land use plan. 

d.	 Maximize geomorphic stability and topographic diversity of the reclaimed 

topography. 

e.	 Eliminate high walls, cut slopes, and/or topographic depressions on site, unless 

otherwise approved. 

f.	 Reconstruct drainage basins and reclaim impoundments to maintain the 

drainage pattern, profile, and dimension to approximate the natural features 

found in nearby naturally functioning basins. 

g.	 Reconstruct and stabilize stream channels, drainages, and impoundments to 

exhibit similar hydrologic characteristics found in stable naturally functioning 

systems. 

h.	 Minimize wind, sheet and rill erosion on/or adjacent to the reclaimed area. 

i.	 There should be no evidence of mass wasting, head cutting, large rills or 

gullies, down cutting in drainages, or overall slope instability on/or adjacent to 

the reclaimed area. Site selection is the favorable method to avoid these issues. 

j.	 Protect seed and seedling establishment (e.g. erosion control matting, 

mulching, hydro-seeding, surface roughening, fencing, etc.) 

3. Describe soil amendments 

a.	 Soil amendment(s) may be used in reclamation if the soil is lacking the necessary 

chemical, biological, physical and /or organic materials to support sustaining growth of 

suitable plant materials. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-29 
 

APPENDIX E—RECLAMATION GUIDANCE
 

b.	 The Operator should state what applying soil amendments is intended to accomplish. Soil 

amendment plans should be provided, including what amendments will be applied, 

method of application, and timing relative to other reclamation activities (i.e. stockpiling, 

seeding, ripping). 

c.	 Soil amendments should be selected based on the undisturbed and/or existing soil 

characteristics (see A. 2. c. iii) and scientific recommendations so as to provide the most 

cost efficient and best assurances for successful reclamation. 

d.	 Soil amendments include but are not limited to the following: Certified weed free grass, 

hay, wood chips or other certified weed free cellulosic materials, gypsum, elemental 

sulfur, and fertilizers. 

4.	 Describe seeding methods 

a. Different plant species may require different conditions (e.g. seeding depth, seed 

scarification, mixing, and timing) for optimal germination success. Seeding methods 

should match germination characteristics of species in the seed mix and consider timing 

of planting to maximize germination and establishment of all reclamation species. 

b.	 The Operator will describe when seeding will occur and specify the methods they will 

use for seeding, including differential handling for different species (e.g. broadcast, 

drilling, imprinting), and seeding depth in the site-specific reclamation plan of the APD. 

Reseeding may need to occur if invasive and/or noxious weeds prevent establishment of 

the species in the seed mix. See Appendix A for references. 

5.	 Seed mixes 

a.	 Providing multifunctional and sustainable seed mixes for interim and final reclamation is 

driven by a desire to increase potential for successful and timely revegetation and site 

stability. Plant diversity and habitat functionality are directly impacted by the seed 

choices applied to an area slated to be reclaimed or restored. To maintain as much 

stability and ecological function, this section makes recommendations to specifically aid 

an operator’s selection process. Please see Appendix A for references. 

i.	 Select appropriate native plant materials based on the pre-disturbance plant 

community composition, site characteristics, and/or ecological site description. 

Seeds may be obtained from commercial sources of certified weed free seed mixes. 

Alternatively, local collections may be used provided they are collected in an area 

without invasive species. Reclamation should succeed using native species if soils 

are properly managed, precipitation is near average for the region, seed mixes are 

carefully selected and seeded areas protected from grazing. 

ii.	 Perennial naturalized species may be used when attempts to reclaim using native 

plants have not succeeded for a minimum of two full growing seasons. 

iii. Based upon site-specific conditions, a decision may be made to use naturalized 

species sooner than identified above and will be used in only unique conditions 

defined in the site-specific reclamation plan in the APD. 

6.	 Describe if and how irrigation techniques will be used in the reclamation plan. 

a.	 Revegetation success is highly dependent on timing and amounts of precipitation. 

However, variable weather in Wyoming can limit or delay successful germination and 

establishment of plants. Irrigation can supplement natural precipitation to insure success of 

newly seeded sites during the initial growth period of the plant. Irrigation practices should 

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APPENDIX E—RECLAMATION GUIDANCE
 

be used carefully and conservatively. Irrigation can be cost prohibitive and should not be a 

requirement for reclamation but used as a tool to enhance vegetation establishment. 

b.	 Both soil and water samples should be tested before application and water source should 

meet appropriate limits for SAR and EC. Special consideration of soil chemistry and 

amendments will be a determining factor for the use of the source water. 

c.	 Water must be utilized from permitted sources (State Engineer’s Office) and from sources 

permitted for irrigation. Produced water, (e.g. coal bed natural gas wells) must adhere to 

discharge permit requirements. 

7.	 Describe best management practices 

a.	 Best Management Practices (BMPs) are techniques that can be applied to surface 

disturbance and reclamation actions to aid in reclamation success. Identify the appropriate 

BMPs during planning and they can guide the surface disturbance and reclamation 

process. Additionally, documenting BMPs provides opportunities to evaluate success, so 

BMPs can be modified for future use in similar conditions. Please see Appendix A for 

recommended BLM and other Best Management Practices. 

8.	 Description of monitoring and reporting protocols for interim reclamation objective. 

The purpose of the Interim Reclamation Objective (IRO) is to reconstruct and revegetate the 

portion of the disturbed land unused for long term production and establish the vegetation 

cover sufficient to maintain a healthy, biologically active topsoil; control erosion; and 

minimize habitat, visual and forage loss during the life of the well and/or facilities. 

The long-term Final Reclamation Objective (FRO) is to return the land to a condition that 

which existed prior to disturbance with allowances for an improved and/or stable ecological 

condition, if possible. 

a. Site monitoring is conducted to observe and keep track of environmental conditions on the 

reclaimed site. Specifically, monitoring is done to document development of the reseeded 

plant community, identification of problem species, soil stability and assess ecosystem 

function. Continued characterization after disturbance and during interim reclamation is 

appropriate for monitoring site maturation and stability, particularly when problematic soil 

conditions or invasive weeds are identified. 

b.	 Vegetation monitoring and disturbed site evaluation for any component of the reclamation 

plan applicable to the APD takes place at intervals agreed to by the BLM and the 

Operator. Generally the intervals for monitoring and reporting will be set annually unless 

otherwise agreed to as a condition to the reclamation plan. Achievement of the IRO by the 

Operator may reduce the time of mandatory monitoring and reporting. These changes to 

monitoring and reporting will be added to the reclamation plan by the BLM. Once the 

disturbed site achieves the approved IRO, the site will still be subject to all applicable 

requirements of the reclamation plan until the FRO is achieved by the Operator and 

approved by the BLM. 

c. Monitoring should be designed and implemented by the Operator to document continuing 

successful reclamation rollover using methodologies approved by BLM. 

i.	 Once the IRO is achieved and reclamation rollover granted by BLM, the Operator 

will continue to monitor the condition of the reclamation, document that the 

revegetation continues to meet IRO. 

ii.	 During monitoring, the Operator will identify potential problems and recommend 

appropriate mitigation measures that can be implemented through BLM’s adaptive 

management process. 

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APPENDIX E—RECLAMATION GUIDANCE
 

d. The required elements of monitoring to assess IRO and FRO will be identified and 

addressed by the Operator in the site-specific reclamation plan. Please see Appendix A for 

additional information. 

D. INDICATORS FOR SUCCESSFUL ACHIEVEMENT FOR THE IRO RESULTING IN 

RECLAMATION ROLLOVER 

1.	 Beginning Monitoring. Monitoring should begin in the first growing season. Rollover 

evaluation is possible after a minimum of two full growing seasons. 

2.	 Irrigation and monitoring. If irrigation is used initially, then the reclamation may be 

evaluated for interim reclamation success two (2) full growing seasons (or the third growing 

season) after irrigation ceases to assure that the vegetation can survive without supplemental 

water. 

3.	 Monitoring results must be from a standardized cover/species protocol approved by 

BLM. 

4.	 Invasive Plants. No invasive weeds will be allowed. Invasive species cover no greater than 

adjacent invasive species cover will be allowed. All other undesirable perennial or annual 

plants as defined in the site-specific APD should be controlled or eradicated on the disturbed 

area. 

5. Undesirable/annual plants. For purposes of successful IRO achievement, the amount 

of invasive plant species should comply with the site-specific reclamation plan. 

6. Vegetation trend. If the vegetation trend towards the IRO achievement is not positive within 3 

full growing seasons without irrigation or 2 years after irrigation (third growing season) ceases, 

the BLM and Operator will determine the needs for the disturbed site. 

7. Erosion. Erosion indicators should be equal to or less than the adjacent reference area. 

E. RECLAMATION MONITORING REPORTING DATA RECOMMENDED TO BE OBTAINED 

AND FILED BY THE OPERATOR (ADAPTED FROM APPENDIX 36 OF THE RAWLINS 

RMP) 

General 

WYW# (Oil and Gas Lease or Right-of-Way (ROW)) 

Project Name: 

Project Type (e.g. Well, Access Road, Pipeline, Facility, Wind) 

Qtr/Qtr Sec, T, R, County, State (or Lat/Long)
 

Pre-Disturbance 

Location of reference area 

Date of reference area inventory/monitoring 

Date of pre-disturbance inventory of disturbed site 

Name of contractor conducting reference and pre-disturbance inventory/monitoring 

Disturbance 

Disturbance Dates 

Start –End dates of monitoring 

Reclamation Type (Interim/Final) 

Name of contractor 

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APPENDIX E—RECLAMATION GUIDANCE
 

Reclamation 

Earthwork Contractor Name 

Earthwork Completion Date 

Soil Preparation method and Depth (prior to re-spreading suitable soil) 

Soil Amendments Used (Describe)
 

Area (Acres or Square Feet) 

Seeding Contractor Name 

Seeding Date
 

Seedbed/Compaction Release Preparation Methods (Describe -Rip, Disc, Harrow, Parabolic) and Depths 

Seeding Method (Drill, Broadcast, Imprint, Depths) 

Copy of Seed Tag (Species percent, Purity percent, Germination percent) 

Actual Seeding Rate (Pure live seed (PLS) Lbs/Acre of each species)
 

Area Seeded (Acres or Square Feet)
 

Noxious/Invasive Plants 

Species Treated 

Contractor Name 

Contractor License # 

Treatment Date 

 Treatment Type (Chemical, Mechanical) 

Chemicals Used and Rates Applied 

Area Treated (Acres or Square Feet) (GIS Extent and Location) 

Monitoring 

Inspector’s Name and affiliation 

Inspection Date 

Time after Seeding (which Growing season) 

Seedlings/Square Feet or Linear Foot Growing 

Percent and Extent of Bare Soil (Describe) 

Percent Ground Cover (Describe)
 

Percent Desirable Species (Describe)
 

Percent Noxious/Invasive Weeds (Describe) 

Describe erosion indicators 

Evidence of Livestock Grazing (Describe) 

IRO objectives met (Yes/No) 

Reference Photos 

Close-Up Photos 

On-site Photos 

Reseeding yes/no, If yes all the above reporting requirements to be filled out.
 

Reporting 

Completed Spreadsheet or Database as defined by BLM 

GIS Layer with Attribute Table with Site Data as Detailed 

Detail Disturbance Extent and Location 

Permanent Photo Reference Point –Describe 

Conclusions/Summary 

 Weed Control Needed - yes/no and explanation 

 Erosion control Needed - yes/no and explanation 

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APPENDIX E—RECLAMATION GUIDANCE 

 Grazing/Predation Issues - yes/no and explanation 

 Other Cultural or Mechanical Needs - yes/no and explanation 

Other 

Mulching/Erosion Netting/Tackifier used – yes/no and describe 

Fenced Location yes/no 

Snow Fencing yes/no 

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APPENDIX E—RECLAMATION GUIDANCE
 

APPENDIX A 

This appendix is designed to provide a very general description of stockpiling suitable soil, irrigation of 

reclamation sites and monitoring vegetation and soils after reclamation. These are not hard and fast 

prescriptions but rather they are best management practices that might best be considered as an outline of 

issues to be considered during reclamation efforts. 

A. Suggestions on Stockpiling Suitable and Unsuitable Soils to Maintain Soil Quality 

Stockpiled suitable soil should not be piled too deeply or too shallowly. Areas of the site to be covered by 

stockpiles of unsuitable soils will be stripped of suitable soil prior to their use. The taller or deeper the 

piles, the more soil is subjected to increasing pressure resulting in compaction. Soil buried deep in the pile 

also has little exposure to oxygen resulting in anaerobiosis; deeply buried soil also has no organic matter 

input. Both of these reduce soil quality. 

Shallow or small suitable soil stockpiles have large footprints on the land surface with the disadvantage of 

covering greater areas of undisturbed soil which will, in turn, require revegetation, resulting in a greater 

overall amount of disturbed soil. Smaller or shallow stockpiles also have a greater surface area per 

volume of soil stored. This increases exposure of the stockpiled soil to wind and water erosion. The 

surface of soil stockpiles should always be vegetated to minimize erosion losses. 

1.	 Salvaged stockpiles of suitable soil should normally be no deeper than 4 meters (13 ft) and 

should be less where possible. 

2.	 Stockpile slopes should not exceed 3:1 angles (20 percent slopes) to allow for seeding and to 

minimize erosion. 

3.	 Suitable soil stockpiles should be located in areas well enough protected to prevent their 

disturbance and contamination by well pad activities. They should not be placed in streambeds 

or ephemeral drainages where they may be washed away. They should be protected from wind 

erosion. Suitable soil should be put on areas that were not skinned. Unsuitable soil should be 

put on areas that were ‘skinned’. 

4.	 Consider a perimeter ditch/berm/fencing or other techniques around the stockpile for topsoil 

conservation and sediment control. 

5.	 All suitable soil stockpiles should be seeded with appropriate vegetation (native locally sourced 

is preferred) to provide cover and protect them from water and wind erosion. Before seeding, 

the stockpile may be scarified along contours to minimize wind and water erosion. 

6.	 If soil horizons or layers are to be stratified during soil salvage (stripping) operations, soil maps 

should be made of the well pad area to identify depths of soil horizons and surface slope. The 

pad area to be cleared of soils should then be divided into strips the size of the blades or 

equipment being used for soil removal. The depth of soil removal from each swath should be 

clearly marked so that equipment operators are removing a uniform layer from each strip. After 

the suitable soil is removed from the area in this manner, the subsoil can then be removed in the 

same fashion, strip by strip, each strip at a uniform depth. 

B. Suggestions on Supplemental Irrigation 

Supplemental irrigation should be scientifically calculated and applied in the initial four to six week 

period of growth of the seedling plants and then ended. Such determination could be the application of an 

amount of irrigation water equivalent to the average or average plus 25 percent of the precipitation 

expected during a given interval. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-35 
 

APPENDIX E—RECLAMATION GUIDANCE
 

C. Suggestions on Vegetation and Soil Monitoring 

Examples of monitoring components are listed below: 

1.	 Reference: http://agriculture.wy.gov/images/stories/pdf/forms/natres/rangelandmonitoring.pdf 

2.	 Operators should use the same locations and methods used at baseline for repeat photography. 

Additional locations may be selected to document progress of reclaimed area to demonstrate 

interim and final reclamation success, and to monitor any identified problems such as erosion. 

The site should be photographed once every year normally during the same time period, from 

the same locations and direction so that photographs are repeated through time. Photographs 

should be taken during the growing season. 

3.	 Weed assessment: Disturbed and reclaimed areas should be evaluated for noxious and invasive 

plants at least annually. Weed control should be promptly implemented by the Operator once 

weed species and infestations are identified. Weed control applied at planned chemical rates at 

times the weed is emerging can have positive impacts in minimizing weed growth through-out 

the year as well as promoting the growth of grass species. The timing of the control should be 

determined by the growth habits of the weed species and when they are most effectively 

assessed. If weeds persist, reseeding the site could be considered as well as the species of grass, 

forb or shrub. 

4.	 Erosion control/soil stability: The reclaimed area should be evaluated for any signs of erosion 

problems annually and when the site is subject to erosional events. Identified erosion features 

should be monitored using repeat photography. Absence of erosion features is a positive 

indication that the soil is stabilizing. 

5.	 Cover and composition data should be used to document that the plant community continues to 

trend toward the requirements to achieve interim and final reclamation targets. The data should 

be used to evaluate if species composition and cover are increasing. These factors should be 

considered relative to the number of species in the seed mix, the selected reference area, and 

offsite responses to seasonal growing conditions. 

6.	 Plant community cover and composition measurements: The Operator should start collecting 

cover and composition data beginning in the first (1st) growing season after disturbance. Data 

should be collected using repeatable methods approved by the appropriate regulatory authority 

(BLM) and should be the same methods that were used to describe vegetation for baseline (or 

reference areas. The same methods should be used each time the vegetation is monitored. 

7.	 Soils should be monitored if reclamation problems suggest that soils might be the problem. 

Such problems include but are not limited to salt crusts, clay crusts, wind and/or water erosion 

and rapid changes in pH (up or down). Recommended soil monitoring would include sampling 

soils and analysis of soil characteristics as described in the main body of Part A, 2 ii. Suitable 

soil inventory. 

E-36 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

APPENDIX E—RECLAMATION GUIDANCE
 

D. Web Links 

Government Documents 

2006 Gold Book: 

http://www.blm.gov/wo/st/en/prog/energy/oil_and_gas/best_management_practices/gold_book.html 

BLM engineering drawings, roads & fences: http://www.blm.gov/nstc/eng/draw.html 

BLM Integrated Vegetation Handbook, 1740-2 is at page: 

http://www.blm.gov/wo/st/en/info/regulations/Instruction_Memos_and_Bulletins/blm_handbooks.ht 

ml 

BLM VRM: http://www.blm.gov/wo/st/en/prog/Recreation/recreation_national/RMS.html 

BLM New Onshore Order #1, May 7-07: 

http://www.blm.gov/wo/st/en/prog/energy/oil_and_gas/Onshore_Order_no1.html 

BLM NSTC: http://www.blm.gov/nstc/ 

EPA: http://www.epa.gov/owow/nps/ and http://www.blm.gov/bmp/ 

USDA Monitoring Manual for Grasslands, Shrublands and Savanna Ecosystems (quantitative Protocols): 

http://usda-ars.nmsu.edu/monit_assess/monmanual_main.php 

Wyoming BLM requirements: http://www.blm.gov/wy/st/en/programs/energy/Oil_and_Gas.html 

Wyoming Climate Atlas: http://www.wrds.uwyo.edu/sco/climate_office.html 

WY DEQ: http://deq.state.wy.us/wqd/watershed/nps/npspg.htm 

NRCS fotog: http://efotg.nrcs.usda.gov/treemenuFS.aspx 

Journals 

American Society of Mining and Reclamation: http://www.asmr.us/
 

Global Restoration Network: www.globalrestorationnetwork.org 

Journal Range Management archives: http://jrm.library.arizona.edu/jrm/
 

National Roadside Vegetation Management Association: http://www.nrvma.org
 

Society for Ecological Restoration (SER): http://www.ser.org/
 

USFS Rocky Mountain Research Station publications: http://www.treesearch.fs.fed.us/pubs/rmrs/
 

Wyoming Native Plant Society: http://uwadmnweb.uwyo.edu/wyndd/wnps/plant_id.htm
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-37 
APPENDIX E—RECLAMATION GUIDANCE
 

MAPS/GIS 

Topo & aerial photos: http://www.usgs.gov/pubprod/aerial.html
 

NRCS National Water and Climate Center: http://www.wcc.nrcs.usda.gov/wcc.html
 

Water Erosion Prediction project: http://octagon.nserl.purdue.edu/weppV1/
 

Wyoming Geographic Information Science Center: http://www.wygisc.uwyo.edu/
 

Mycorrhizae (Biological Soil Crusts)
 

http://mycorrhiza.ag.utk.edu/default.html
 

http://invam.caf.wvu.edu/index.html
 

http://www.ars.usda.gov/is/pr/2003/030205.htm
 

http://soilcrust.org
 

OIL/GAS 

Completion and workover wastes: http://www.epa.gov/wastes/nonhaz/industrial/special/oil/wc.pdf 

Dust suppression: http://www.oznet.ksu.edu/Stevenson/Dust percent20Manual percent20 

percent20102704.pdf 

Hydraulic Fracturing (Fracking or Frac Job): 

http://test.earthworksaction.org/index.php/issues/detail/hydraulic_fracturing_101 

http://www.epa.gov/hfstudy/HF_Study__Plan_110211_FINAL_508.pdf 

National LTAP & TTAP Rural Roads: http://www.ltap.org/ 

Oil & Gas Production wastes: http://www.epa.gov/wastes/nonhaz/industrial/special/oil/ 

Power lines: http://www.aplic.org/ 

Produced water: http://www.iogcc.state.ok.us/Websites/iogcc/producedwater/popup.htm 

The T2

/LTAP Center University of Wyoming: http://wwweng.uwyo.edu/wyt2/ 

Western Governors CBM BMPs: http://www.westgov.org/wga/initiatives/coalbed/CoalBedMethane.pdf 

Wyoming Oil and Gas Commission requirements: http://wogcc.state.wy.us/ 

Restoration Handbooks 

Bags Quiet Presence NRCS: http://www.wy.nrcs.usda.gov/Plant/tech_notices.html 

Dryland pastures: http://msuextension.org/publications/AgandNaturalResources/EB0019.pdf 

Handbook of Western Reclamation Techniques: 

http://www.techtransfer.osmre.gov/NTTMainSite/Library/hbmanual/westrecl/front-matter.pdf 

Restoring Western Ranges and Wild lands: http://www.fs.fed.us/rm/pubs/rmrs_gtr136_3.pdf 

Solid Minerals reclamation handbook: http://www.blm.gov/nhp/efoia/wo/fy01/ib2001-081attach.pdf 

Scientific Literature 

An Introduction to using native plants in Restoration: 

http://www.nrcs.usda.gov/wps/portal/nrcs/main/national/plantsanimals/plants/techpub 

Geology and Plant life: 

http://www.nrcs.usda.gov/wps/portal/nrcs/main/national/plantsanimals/plants/techpub 

Managing Arid and semi-arid watersheds: http://www.wy.blm.gov/botany/wyspecies.htm 

E-38 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX E—RECLAMATION GUIDANCE
 

http://water.epa.gov/lawsregs/lawsguidance/cwa/wetlands/laws_index.cfm 

Revegetation Abstracts: 

http://www.nrcs.usda.gov/wps/portal/nrcs/main/national/plantsanimals/plants/techpub 

Sagebrush: http://sagemap.wr.usgs.gov/SagebrushAssessment.aspx 

Salt tolerant plants: http://www.ussl.ars.usda.gov/pls/caliche/Halophyte.query 

USDA Plant database: http://plants.usda.gov/ 

Wyoming Natural Diversity Database: http://uwadmnweb.uwyo.edu/wyndd/ 

Wyoming Plant Materials Technical notes: 

http://www.nrcs.usda.gov/wps/portal/nrcs/main/national/plantsanimals/plants/techpub 

Wyoming Reclamation and Restoration Center: http://uwadmnweb.uwyo.edu/WRRC/ 

Educational Opportunities and Workshops 

Wyoming Reclamation and Restoration Center: http://uwadmnweb.uwyo.edu/WRRC/ 

Seed sources 

Guidebook to Great Basin seeds: 

http://www.blm.gov/id/st/en/info/publications/technical_bulletins/TB05-4.html 

Native Plant Propagation Protocols: http://nativeplants.for.uidaho.edu/network/ 

Native Seed Network: http://www.nativeseednetwork.org/index 

Oregon state Seed Lab: quality testing of native seed: http://seedlab.oregonstate.edu/u 

Seed testing protocols: http://www.aosaseed.com/publications.htm 

Wyoming State Seed Lab: http://uwacadweb.uwyo.edu/seedlab/default.htm 

Soil 

Glossary of Soil Science Terms: http://soils.usda.gov/technical/ 

NCSS Web Soil Survey: 

http://www.nrcs.usda.gov/wps/portal/nrcs/main/national/plantsanimals/plants/techpub 

http://www.nrcs.usda.gov/ 

http://websoilsurvey.nrcs.usda.gov/app/HomePage.htm 

NRCS Soil Quality Publications: http://soils.usda.gov/technical/ 

Soil series name search: http://soils.usda.gov/technical/classification/ 

Weeds 

Halogeton: http://www.ars.usda.gov/Services/docs.htm?docid=9937 

Weed Science Society of America: http://www.wssa.net 

TNC Invasive species (weeds): http://tncinvasives.ucdavis.edu/ 

Wildlife 

Important Wildlife Habitats: http://wgfd.wyo.gov/web2011/wildlife-1000426.aspx 

Sage grouse range wide forum links: http://sagegrouse.ecr.gov/?link=110 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-39 
 

APPENDIX E—RECLAMATION GUIDANCE 

Recommendations for Development of Oil and Gas Resources within Crucial and Important Habitats: 

http://wgfd.wyo.gov/web2011/Departments/Wildlife/pdfs/HABITAT_OILGASRECOMMENDATIO 

NS0000333.pdf 

E-40 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX E—RECLAMATION GUIDANCE
 

E. List of Participants 

This document has been two years in the making and meetings included training sessions and visits to 

field sites in the general vicinity of the CD-C. The contributors of this document were members of an ad 

hoc committee that varied in size from meeting to meeting. This ad hoc group was created through the 

efforts of the Governor Freudenthal’s Planning Office. Some of the participants were advisory only (AO) 

but others were involved in the writing, review and synthesis (WRS) of the final project. One member of 

the committee acted as the Chair. 

Considerable review, both formal and informal, of this document was provided by the committee and an 

intensive external review was provided by an anonymous consultant. 

BLM 

Adrienne Pilmanis (WRS) 

Bill Lanning (AO) 

Eldon Allison (AO) 

Rebecca Spurgin (AO) 

Skip Stonesifer (AO)
 

Tom Lahti (AO) 

BLM Contractor 

Steve Moore (AO) 

BP America Production Company 

Gary Austin (WRS) 

Coalition of Local Governments 

David Allison (WRS) 

Jean Dickinson (WRS) 

Mary Thoman (AO) 

Tim Morrison (WRS) 

CSR 

Steven Paulsen (WRS) 

Department of Agriculture 

Chris Wichmann (AO) 

Department of Environmental Quality 

Carol Bilbrough (WRS) 

Mark Conrad (WRS) 

Devon 

Bill Skelton (AO) 

Craig Goodrich (AO) 

Dru Bower Moore (WRS) 

Nick Agopian (AO) 

Randy Bolles (AO) 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-41 
APPENDIX E—RECLAMATION GUIDANCE
 

Governor’s Planning Office 

Steve Furtney (WRS) 

Wyoming Game and Fish Department 

Mary Flanderka (WRS and Meeting Coordinator) 

UW Reclamation and Restoration Center 

Peter D. Stahl (WRS) 

Stephen Williams (WRS) 

E-42 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX E—RECLAMATION GUIDANCE
 

BLM Rollover Criteria 

Continental Divide-Creston Environmental Impact Statement 

INTRODUCTION
 

It is reasonable to anticipate that successful reclamation activities within the Continental Divide-Creston 

project area will be difficult. This can be observed by reviewing Map 3.3-5 which shows an estimated 75 

percent of the area with “poor” reclamation potential. Reclamation potential of soils in the CD-C project 

area is limited by saline/sodic soil conditions and either clayey or sandy soil textures (Table 3.3-1). In 

addition to these soil limitations, low annual precipitation of 6 – 10 inches in conjunction with erosion by 

wind and water will make successful reclamation difficult to attain quickly. Periodic droughts and 

extreme climatic conditions further complicate successful reclamation. 

RECLAMATION PERFORMANCE MONITORING 

Monitoring should include both qualitative data collection techniques and quantitative data collection. 

Qualitative evaluation of the interim reclamation can include the evaluation of soil movement (rills, sheet 

flow, petal-stilling, etc.), vegetative components (presence/absence of species, estimation of population 

and the population’s condition) as well as visual contrast. The quantitative data collection should include 

both aerial and basal cover. The data should note the species during the evaluation. It is important to use 

the same methods for qualitative and quantitative data collection during each site evaluation to show a 

trend and display that the Interim Rollover Objective (IRO) has been met. 

DISTINCTION BETWEEN INTERIM AND FINAL RECLAMATION 

Two types of reclamation will occur within the CD-C area. Final reclamation occurs when all facilities 

are removed (e.g. plugged and abandoned, the site is re-contoured back to its original topography, and 

adequate native vegetation communities similar to those originally disturbed are established including, in 

part, weed control and stable soils). When completed and accepted the company’s bond is released and 

the site returns to BLM control. High desert sites, such as those found at CD-C, are slow to return to their 

original vegetative states, often requiring decades of time even with successful reclamation. 

Interim reclamation occurs within the next growing season on any disturbance not needing to be 

continuously disturbed by ongoing operational activities. The existing pipelines, roadsides, and portions 

of well pads not needed for operations are examples of short-term disturbance which requires interim 

reclamation. Areas with interim reclamation may be disturbed again by new construction or operational 

activities that may occur. Those areas will be reclaimed after any disturbance to maintain interim 

reclamation. Areas of a well pad might also remain undisturbed until final reclamation is achieved. 

Circumstances will vary site by site over the course of the project. 

PURPOSE OF A DISTURBANCE CAP 

A disturbance cap is a limit on the extent of surface disturbance that can occur within a given area. A 

disturbance cap that has potential to limit development activities within an area creates a direct incentive 

for developers to conduct successful reclamation on disturbed lands. Once the disturbance cap is reached 

further development is constrained until the disturbance acreage is reduced as a result of attaining the 

IRO. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-43 
APPENDIX E—RECLAMATION GUIDANCE
 

ROLLOVER CONCEPT
 

Surface disturbance that has been reclaimed to the IRO standard will be classified as successful interim 

reclamation and this acreage can then be deducted from the number of acres counted as surface 

disturbance (or rolled over) for the area, and further disturbance could occur under the disturbance cap. 

The conditions under which interim reclamation can be considered acceptable for “rollover” are crucial 

for managing disturbance and the effects thereof on the natural resources BLM manages. 

OBJECTIVES FOR INTERIM RECLAMATION 

Work conducted in part by the State of Wyoming, local Conservation Districts, the University of 

Wyoming, participating leaseholders, oil and gas developers, and the BLM led to the development of 

several objectives for interim reclamation. It was agreed that the purpose of the IRO is to identify when 

reconstruction and re-vegetation activities on disturbed lands is adequate for rollover credit for the 

companies. Rollover credit could not be applied to the portion of the disturbed surface used for long-term 

production and continuous disturbance. 

The IRO is to establish vegetation cover sufficient to maintain a healthy, biologically active topsoil; 

control erosion; and minimize habitat, visual, and forage loss during the life of the disturbed area. In 

addition, it was determined that the elimination of noxious weeds and the control of invasive non-native 

weeds must have occurred for successful attainment of IRO. 

RECLAMATION ROLLOVER CRITERIA 

The reclamation success standards listed below are the measures that would be used to evaluate whether 

the interim reclamation is successful: 

 The area is revegetated with a stable, approved plant community. 

 Vegetative cover is sufficient to maintain a healthy, biologically active topsoil. 

 Erosion is controlled. 

 Habitat, visual, and forage loss is minimized. 

 No noxious weeds are present. 

ACCOUNTING FOR DISTURBANCE TRACKING 

Once a proposal for surface disturbance is approved and constructed the company will record the as-built 

disturbance using a GPS system compatible with the BLM’s system. The extent of all disturbance from 

the approved proposal will be determined. The company will maintain a record of the extent of 

disturbance, generally by aliquot section, Township and Range, or by lease as applicable. 

When further disturbance within an area is proposed the company will submit its existing disturbance 

records for the area in question to the BLM along with the rest of its plan of development. The BLM will 

review the existing extent of disturbance. 

If the disturbance extent meets or exceeds the applicable disturbance extent cap then the BLM will 

request from the Company why further disturbance should be approved. Based on the response from the 

company the BLM will consider the proposal in the site-specific NEPA document for the proposal tiered 

to the CD-C Record of Decision (ROD). 

If the new disturbance extent proposed does not meet or exceed the disturbance cap for the area in 

question the BLM will evaluate the proposal with a site-specific NEPA document and determine what, if 

any, disturbance will be approved. Once construction activities are completed the company will supply 

E-44 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX E—RECLAMATION GUIDANCE
 

the BLM with the new as-built surface disturbance extent as provided above. The new disturbance 

information will be added to the existing data to determine the current disturbance figure. 

Reclamation of the disturbed surface by the companies will be monitored by the companies at least 

annually as provided in the reclamation monitoring provisions of the Reclamation Plan. When the 

company feels disturbed sites have attained the IRO described above, the company may propose to the 

BLM to withdraw the acreage meeting the IRO from the surface disturbance acreage estimate. The BLM 

will reduce the disturbance figure when it is determined by the BLM that the IRO has been met, from data 

supplied by the company. The BLM may consult with cooperating agencies in its assessment of the data 

but the BLM is the final decision-maker on whether the IRO has been attained. 

In the event areas meeting the IRO that have been removed from the disturbance are in turn re-disturbed, 

the acreage re-disturbed will be added back into the surface disturbance acreage estimate. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 E-45 
APPENDIX F: WATER RESOURCES SUPPORTING DATA 

List of Tables 

Table F-1. BLM range gage yearly precipitation averages (gages within and adjacent to the 

CD-C project area)............................................................................................................... F-1 

Table F-2. Flow statistics from USGS gaging stations located within and adjacent to the CD-C 

project area........................................................................................................................... F-2 

Table F-3. Surface water rights and use within 1 mile of the CD-C project area ................................. F-3 

Table F-4. Surface water rights within 1 mile of the CD-C project area ............................................... F-4 

Table F-5. WDEQ use classifications ................................................................................................. F-22 

Table F-6. WDEQ use-classified water bodies near and in the CD-C project area ............................. F-23 

Table F-7. Surface water quality at selected sites within and adjacent to the CD-C project area ....... F-24 

Table F-8. Muddy Creek water quality ............................................................................................... F-25 

Table F-9. 2010 303(d) water bodies in the CD-C project area with impairments or threats ............. F-26 

Table F-10. Water-bearing characteristics of geologic formations in the Washakie and Great 

Divide structural basins ..................................................................................................... F-27 

Table F-11. Existing groundwater rights within 1 mile of the CD-C project area, February 2011 ....... F-28 

Table F-12. Groundwater rights within 1 mile of the CD-C project area .............................................. F-29 

Table F-13. Groundwater quality parameters for selected aquifers associated with the CD-C 

project area......................................................................................................................... F-57 

Table F-14. Selected water quality parameters in flowing wells and springs within and adjacent 

to the CD-C project area .................................................................................................... F-58 

 List of Maps 

Map F-1. Surface water monitoring sites within and adjacent to the CD-C project area ...................... 59 

Map F-2. Surface water rights within and adjacent to the CD-C project area ....................................... 60 

Map F-3. Groundwater rights within and adjacent to the CD-C project area ........................................ 61 

Map F-4. Groundwater monitoring sites within and adjacent to the CD-C project area ....................... 62 

Map F-5. Generalized potentiometric surface and groundwater flow direction, Wasatch Aquifer ....... 63 

Map F-6. Generalized potentiometric surface and groundwater flow direction, Mesaverde Aquifer ... 64 

Map F-7. Generalized potentiometric surface and groundwater flow direction, Tensleep Aquifer ...... 65 

Map F-8. Generalized potentiometric surface and groundwater flow direction, Madison Aquifer ....... 66 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-i 
 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-1. BLM range gage yearly precipitation averages (gages within and adjacent to the CD-C 

project area) 

Name Location Record 

Minimum 

(inches) 

Maximum 

(inches) 

Average 

(inches) 

Adams SWSW Section 11 T17N: R92W 1987 - 2010 4.58 12.91 8.52 

Creston SESE Section 22 T20N: R92W 1986 - 1996, 

1998 - 2010 4.95 11.70 7.96 

Cyclone Rim SWSW Section 36 T25N: R96W 1986 - 2010 2.51 8.08 5.04 

Echo Springs NENE Section 6 T17N: R92W 1961 - 1970, 

1974 - 2010 4.03 14.74 7.57 

Flat Top SESW Section 31 T15N: R93W 

1974 - 1983, 

1985 - 2003, 

2005 - 2010 

3.73 14.50 9.28 

LaClede SWSW Section 30 T18N: R93W 1987 - 2010 3.57 9.26 6.66 

Little Robber SWSW Section 7 T14N: R91W 

1961 - 1971, 

1974 - 1987, 

1989 - 2010 

4.28 15.14 9.59 

Man and Boy SESW Section 2 T17N: R95W 

1963 - 1964, 

1966 - 1972, 

1974 - 1976, 

1978 - 1982, 

1984 - 1988, 

1990 - 2010 

3.85 10.74 7.14 

Mexican Graves NWSE Section 22 T16N: R93W 

1961, 

1964 - 1968, 

1970 - 1972, 

1974 - 1983, 

1985 - 1986, 

1988 - 2010 

5.04 13.33 7.74 

Mud Springs NESW Section 7 T22N: R91W 1986 - 2010 3.55 9.27 6.52 

North Tipton SESW Section 21 T21N: R96W 

1987, 

1989 - 1994, 

1996 - 2002, 

2004 - 2010 

3.38 8.62 6.24 

Tipton NESE Section 36 T19N: R96W 1986 - 1991, 

1993 - 2010 4.50 11.07 8.44 

Willow Creek NWNE Section 32 T16N: R94W 

1980 - 1981, 

1983, 

1986 - 1993, 

1997 - 2010 

3.16 12.10 7.35 

Average for all Gages = 7.54 

Minimum Average for all Gages = 3.93 

Maximum Average for all Gages = 11.65 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-1 
 

 

 

 

 

 

 

 

 

APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-2. Flow statistics from USGS gaging stations located within and adjacent to the CD-C project 

area 

Station Name 

Station 

Number 

Drainage 

Area 

(sq. mi.) 

Period of 

Record 

Mean 

Flow1 

(cfs) 

Mean 

Annual 

Runoff 

(acft/yr) 

Median 

Flow2 

(cfs) 

Min. 

Flow2 

(cfs) 

Max. 

Flow 

(cfs) 

Date 

Upper Green Basin (HUC 140401) 

Bitter Creek 09216545 308 7/1975 – 

9/1981 3.7 2,773 1.0 0 333 

7/25/1975 

White-Yampa Basin (HUC 140500) 

Little Snake River 

near Dixon 09257000 988 

10/1/1910 -

9/30/1923 

10/1/1938 – 

9/30/1971 

4/1/1972 – 

9/30/19974

 514 372,355 100 0 10,400 

5/16/1984 

Muddy Creek near 

Baggs 09259000 1,257 

(1,187)3 

10/1/1987 -

9/30/1991 14.8 10,675 2.8 0.03 632 

3/23/1988 

Muddy Creek 

below Young Draw 

near Baggs 

09258980 1,150 4/17/2004 -

2/15/2011 18.0 13,066 1.1 0.07 499 

3/8/2007 

Great Divide Basin (HUC 140402) 

Separation Creek 

near Riner 09216527 53 10/1/1975 -

9/30/1981 1.8 1,300 0 0 76 

4/20/1980 

Separation Creek 

at upper station 

near Riner 

09216525 42 7/1/1975 -

9/30/1975 1.3 na 0.8 0.5 21 

9/11/1975 

1	 Over period of record (cubic feet per second) 2	 Of mean daily values. 3	 Contributing drainage area. 4	 Daily flow measurements were only made from April through October during this time; not included in calculation of mean or 

median flow. 

Source: USGS 2007and 2011 

F-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-3. Surface water rights and use within 1 mile of the CD-C project area 

SEO Use Designation (As Assigned) Surface Water Rights 

Stock 291 

Irrigation; Stock 13 

Miscellaneous 13 

Irrigation 12 

Fish Propagation; Stock; Wetlands; Combined Beneficial Use 6 

Reservoir Supply 6 

Domestic; Irrigation; Stock 5 

Fish Propagation; Stock; Wetlands 4 

Industrial 4 

Irrigation; Stock; Combined Beneficial Use 4 

Industrial; Temporary; Combined Beneficial Use 3 

Stock; Wetlands; Combined Beneficial Use 3 

Wetlands 3 

Flow Through Non-consumptive; Reservoir Supply 2 

Unspecified 1 

Domestic; Irrigation 1 

Domestic; Irrigation; Stock; Combined Beneficial Use 1 

Drilling; Industrial; Oil Refining/Production; Temporary 1 

Fish Propagation; Flood Control; Stock 1 

Fish Propagation; Recreation; Stock; Combined Beneficial Use 1 

Fish Propagation; Reservoir Supply 1 

Fish Propagation; Stock; Combined Beneficial Use 1 

Industrial; Irrigation; Stock; Combined Beneficial Use 1 

Irrigation; Reservoir Supply 1 

Irrigation; Reservoir Supply; Stock 1 

Reservoir Supply; Stock 1 

Stock; Wildlife 1 

Wildlife 1 

Total 383 

Use Included in SEO Designation Surface Water Rights 

Stock 334 

Irrigation 39 

Wetlands 16 

Fish Propagation 14 

Miscellaneous 13 

Reservoir Supply 12 

Industrial 9 

Domestic 7 

Temporary 4 

Flow Through Non-consumptive 2 

Wildlife 2 

Oil Refining/Production 1 

Flood Control 1 

Recreation 1 

Unspecified 1 

Total 1 456 

1

 Total (456) exceeds the number of permitted surface water rights (383) since individual rights may have 

multiple uses 

Source: SEO 2011 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-3 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Se c QtrQtr Total Flow Source Name 

CR08/504 06/26/1974 -- USDI BLM Toad Stool (Index #4321) Stock Reservoir STO 013N 091W 4 NW1/4SW1/4 7.24 Toad Stool 

P18111S 03/20/2006 Fully Adjudicated -- H & C LLC #4 STOCK RESERVOIR STO 013N 091W 4 SW1/4SE1/4 -- Sec 4 Dra

P7747S 06/26/1974 Fully Adjudicated -- Toad Stool (Index #4321) Stock Reservoir STO 013N 091W 4 NW1/4SW1/4 7.24 Toad Stool 

P18265S 03/20/2006 Fully Adjudicated -- CHANT #2 STOCK RESERVOIR STO 013N 091W 5 NE1/4SW1/4 -- Flute Dra

P5313R 07/27/1940 Unadjudicated

 US DEPARTMENT OF 

INTERIOR, DIV. OF 

GRAZING 

Cottonwood Reservoir STO 013N 091W 6 NE1/4NE1/4 96.21 Percy Dra

P17348D 03/12/1928 Fully Adjudicated P.E. POULSON Muddy Ditch DOM; IRR 013N 091W All -- 1.09 Jackson Draw

2 

CR11/096 09/27/1985 -- USDI BLM Detention 1392 #2 Stock Reservoir STO 013N 092W 1 NW1/4SW1/4 19.18 Cottonwood 

P9775S 09/27/1985 Fully Adjudicated -- Detention 1392 #2 Stock Reservoir STO 013N 092W 1 NW1/4SW1/4 19.18 Cottonwood 

P11313S 09/11/1991 -- -- Exclosure Stock Reservoir STO 013N 092W 3 NW1/4NE1/4 3.78 Dogleg Dr

P12793S 03/22/1996 -- -- Washout (0312) Stock Reservoir STO 013N 092W 3 NE1/4SE1/4 2.73 Dogleg Dr

CR11/105 09/12/1985 -- USDI BLM Lost Sheep Stock Reservoir STO 013N 093W 1 NW1/4SE1/4 3.3 Lost Sheep P9759S 09/12/1985 Fully Adjudicated -- Lost Sheep Stock Reservoir STO 013N 093W 1 NW1/4SE1/4 3.3 Lost Sheep 

P11358S 09/09/1991 -- -- McIntosh Stock Reservoir STO 013N 093W 2 NW1/4NE1/4 4.3 McIntosh D

P6576S 12/10/1969 Fully Adjudicated USDI BLM Rocky Ridge Pit Stock Reservoir STO 014N 091W 5 SW1/4SE1/4 1.98 Reef Dra

CR05/591 12/10/1969 -- USDI BLM Rocky Ridge Pit Stock Reservoir STO 014N 091W 5 SW1/4SE1/4 1.98 Reef Dra

P6656S 03/09/1970 Fully Adjudicated USDI BLM Bottle Stock Reservoir STO 014N 091W 8 SE1/4NE1/4 1.16 Bottle Dra

CR05/588 03/09/1970 -- USDI BLM Bottle Stock Reservoir STO 014N 091W 8 SE1/4NE1/4 1.16 Bottle Dra

P6655S 03/09/1970 Fully Adjudicated USDI BLM Thunder Stock Reservoir STO 014N 091W 17 SW1/4NE1/4 1.99 Thunder D

CR05/589 03/09/1970 -- USDI BLM Thunder Stock Reservoir STO 014N 091W 17 SW1/4NE1/4 1.99 Thunder D

CR05/583 12/10/1969 -- USDI BLM Tangled Chain Pit Stock Reservoir STO 014N 091W 28 SW1/4NE1/4 1.97 Impossible 

P17276S 07/26/2004 Fully Adjudicated -- HICKS STOCK RESERVOIR STO 014N 091W 32 SE1/4SE1/4 -- -- P18054S 03/20/2006 Complete -- H & C #3 DAM STOCK RESERVOIR STO 014N 091W 32 -- -- Impossible 

P6558S 12/08/1969 Fully Adjudicated USDI BLM "V" Spreader Pit Stock Reservoir STO 014N 092W 1 NW1/4SE1/4 0.92 Tom Dra

F-4 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

CR05/593 12/08/1969 -- USDI BLM "V" Spreader Pit Stock Reservoir STO 014N 092W 1 NW1/4SE1/4 0.92 Tom Dra

P11322S 09/04/1991 -- -- Big Robber Stock Reservoir STO 014N 092W 8 SE1/4NW1/4 4.32 Robber Flat 

P11323S 09/04/1991 -- -- Little Robber Stock Reservoir STO 014N 092W 12 SE1/4SW1/4 0.45 Robbers Play

P9534R 09/22/1988 Fully Adjudicated -- Little Robber Detention Dam Reservoir FIS; STO; COMBBU 014N 092W 14 NW1/4NE1/4 550.58 Little Robbers 

CR13/055 09/22/1988 -- USDI BLM Little Robber Detention Dam Reservoir FIS; FLO; STO 014N 092W 14 NW1/4NE1/4 550.58 Little Robbers 

P11324S 09/04/1991 -- -- Wild Horse Stock Reservoir STO 014N 092W 15 NW1/4NE1/4 15.76 Wagner G

P10331S 10/05/1987 -- -- Big Robber Detention Dam No. 1 Stock Reservoir STO 014N 092W 17 NE1/4NW1/4 2.50 Muddy CrowP9780S 09/27/1985 Fully Adjudicated -- Trail Stock Reservoir STO 014N 092W 20 SW1/4NW1/4 8.40 Little Robbers CR11/088 09/27/1985 -- USDI BLM Trail Stock Reservoir STO 014N 092W 20 SW1/4NW1/4 8.40 Little Robbers 

P9756S 09/12/1985 Fully Adjudicated -- Rattlesnake Stock Reservoir STO 014N 092W 23 NE1/4NW1/4 14.70 Rattlesnake 

CR11/089 09/12/1985 -- USDI BLM Rattlesnake Stock Reservoir STO 014N 092W 23 NE1/4NW1/4 14.70 Rattlesnake 

P11325S 09/04/1991 -- -- Detention 1492-3 Stock Reservoir STO 014N 092W 26 SE1/4SE1/4 5.35 Muddy Cr

P11326S 09/04/1991 -- -- Detention 1492 #1 Stock Reservoir STO 014N 092W 28 NW1/4NE1/4 1.80 North Fo

Cottonwood 

P6563S 12/08/1969 Fully Adjudicated USDI BLM Pocket Stock Reservoir STO 014N 092W 29 SW1/4NE1/4 1.97 Pocket D

CR05/592 12/08/1969 -- USDI BLM Pocket Stock Reservoir STO 014N 092W 29 SW1/4NE1/4 1.97 Pocket D

P6571S 12/10/1969 Unadjudicated USDI BLM Dike View Stock Reservoir STO 014N 092W 32 NW1/4NE1/4 1.97 Dike View 

P11314S 09/11/1991 -- -- South Flat Top #2 Stock Reservoir STO 014N 092W 33 NW1/4SW1/4 7.47 Dogleg D

P9757S 09/12/1985 Fully Adjudicated -- Detention Dam 1682 #4 Stock Reservoir STO 014N 092W 34 NE1/4NE1/4 10.0 Dike View 

CR11/098 09/12/1985 -- USDI BLM Detention Dam 1682 #4 Stock Reservoir STO 014N 092W 34 NE1/4NE1/4 10.0 Dike View 

P13758S 02/01/2000 Unadjudicated HOWARD B. LEE FAMILY Lee Family #1 Stock Reservoir STO 014N 092W 36 NE1/4SW1/4 -- Lee Dra

P7717S 06/26/1974 Fully Adjudicated USDI BLM West Flattop (Index #4358) Stock Reservoir STO 014N 093W 3 SE1/4NW1/4 2.98 South Fork 

Flattop D

CR08/520 06/26/1974 -- USDI BLM West Flattop (Index #4358) Stock Reservoir STO 014N 093W 3 SE1/4NW1/4 2.98 South Fork 

Flattop D

P10872S 01/24/1990 Unadjudicated -- Center Stock Reservoir STO 014N 093W 10 SE1/4SW1/4 1.01 Upper Hango

P10873S 01/24/1990 Unadjudicated -- Tip Top Stock Reservoir STO 014N 093W 13 NW1/4NE1/4 0.95 Upper Top 

P11332S 09/04/1991 -- -- Morgan Stock Reservoir STO 014N 093W 14 NE1/4NW1/4 1.86 Morgan D

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P11333S 09/04/1991 Unadjudicated -- SW Flat Top Stock Reservoir STO 014N 093W 15 SW1/4NE1/4 1.21 Sand Cre

P11315S 09/11/1991 -- -- South Flat Top Stock Reservoir STO 014N 093W 24 SW1/4SE1/4 0.95 Nubs Dra

P11327S 09/04/1991 -- -- Standard Road Stock Reservoir STO 015N 092W 5 SE1/4NW1/4 2.39 Glenarm C

P11328S 09/04/1991 -- -- South Barrel #5 Stock Reservoir STO 015N 092W 7 NW1/4NW1/4 1.40 South Barre

P11329S 09/04/1991 -- -- South Muddy #2 Stock Reservoir STO 015N 092W 11 NW1/4NW1/4 1.71 Highway Mud 

P19253S 07/17/2009 Incomplete BLM BLUE GAP PIT # 3 STO 015N 092W 13 NE1/4SW1/4 -- Pit #3 DrP9013R 07/05/1985 Unadjudicated -- Mexican flats Water Disposal Reservoir IND; TEM; COMBBU 015N 092W 17 SW1/4NE1/4 28.59 Soco DraP18862S 03/19/2008 Unadjudicated USDI BLM Mexican Flats Pit #1 Stock Reservoir STO 015N 092W 17 SW1/4SE1/4 -- Soco Dra

P7721S 06/26/1974 Fully Adjudicated USDI BLM Blue Gap (Index #4319) Stock Reservoir STO 015N 092W 23 NW1/4NE1/4 3.79 Little Blue Ga

P9659S 03/25/1985 Fully Adjudicated -- Blue Gap Pit Stock Reservoir STO 015N 092W 23 NW1/4NE1/4 3.49 Little Blue Ga

CR11/084 03/25/1985 -- USDI BLM Blue Gap Pit Stock Reservoir STO 015N 092W 23 NW1/4NE1/4 3.49 Little Blue Ga

CR08/518 06/26/1974 -- USDI BLM Blue Gap (Index #4319) Stock Reservoir STO 015N 092W 23 NW1/4NE1/4 3.79 Little Blue Ga

P19252S 07/17/2009 Incomplete BUREAU OF LAND MANAGEMENT BLUE GAP PIT # 4 STO 015N 092W 24 SE1/4NE1/4 -- Pit # 4 Dr

P11330S 09/04/1991 -- -- Detention 1592-2 Stock Reservoir STO 015N 092W 28 SE1/4SW1/4 6.85 Bunny Drop 

P9781S 09/27/1985 Fully Adjudicated -- Blue Gap Stock Reservoir STO 015N 092W 29 NE1/4NW1/4 2.4- Blue Gap D

CR11/083 09/27/1985 -- USDI BLM Blue Gap Stock Reservoir STO 015N 092W 29 NE1/4NW1/4 2.4- Blue Gap D

P9783S 09/27/1985 Fully Adjudicated -- Dad Larsen Detention 1593 #6 Stock Reservoir STO 015N 093W 14 SE1/4NE1/4 19.84 West Flattop 

CR11/091 09/27/1985 -- USDI BLM Dad Larsen Detention 1593 #6 Stock Reservoir STO 015N 093W 14 SE1/4NE1/4 19.84 West Flattop 

P11336S 09/04/1991 -- -- South Barrel #4 Stock Reservoir STO 015N 093W 15 SE1/4SE1/4 1.37 Upper Painte

P7746S 06/26/1974 Fully Adjudicated USDI BLM Five Coyote (Index #4352) Stock Reservoir STO 015N 093W 21 NW1/4SE1/4 5.10 Five Coyote 

CR08/524 06/26/1974 -- USDI BLM Five Coyote (Index #4352) Stock Reservoir STO 015N 093W 21 NW1/4SE1/4 5.10 Five Coyote 

P7719S 06/26/1974 Fully Adjudicated USDI BLM Upper Painted (Index #4354) Stock Reservoir STO 015N 093W 22 SW1/4SE1/4 2.71 Upper Painte

F-6 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

CR08/522 06/26/1974 -- USDI BLM Upper Painted (Index #4354) Stock Reservoir STO 015N 093W 22 SW1/4SE1/4 2.71 Upper Painte

CR08/523 06/26/1974 -- USDI BLM Lower Painted (Index #4353) Stock Reservoir STO 015N 093W 22 NW1/4NW1/4 2.98 Lower Painte

P11338S 09/04/1991 -- -- Flat Top #1 Stock Reservoir STO 015N 093W 27 SW1/4NE1/4 3.34 Twin Dra

CR08/521 06/26/1974 -- USDI BLM Upper Twin (Index #4355) Stock Reservoir STO 015N 093W 33 SE1/4NE1/4 2.98 Twin Dra

P10217R 09/07/1995 Fully Adjudicated Little Snake River Conservation District Upper Dike Reservoir STO; WET; COMBBU 016N 092W 5 -- 37.4 Muddy CrP10218R 09/07/1995 Fully Adjudicated Little Snake River Conservation District Middle Dike Reservoir STO; WET; COMBBU 016N 092W 5 -- 40.2 Muddy Cr

P10219R 09/07/1995 Fully Adjudicated Little Snake River Conservation District Lower Dike Reservoir STO; WET; COMBBU 016N 092W 5 SW1/4SW1/4 159.00 Muddy CrP16959D 03/13/1925 Unadjudicated Geo. W. Dew Dew Ditch No. 1 IRR 016N 092W 5 SE1/4SW1/4 1.42 Muddy Cr

P16960D 03/13/1925 Fully Adjudicated Geo. W. Dew Dew Ditch No. 2 IRR 016N 092W 5 SE1/4SW1/4 1.97 Muddy CrP31451D 09/07/1995 Fully Adjudicated Little Snake River Conservation District Muddy Creek Duck Pond Ditch RES 016N 092W 5 -- 0.00 Muddy Cr

P7403E 05/27/2004 Unadjudicated Steve F. Adams 

Duck Pond #5 Enl. of the 

Muddy Creek Duck Pond 

Supply Ditch 

FTH; RES 016N 092W 5 -- -- Muddy Cr

CC47/312 03/13/1925 -- GEORGE W. DEW Dew Ditch No. 2 IRR 016N 092W 5 SE1/4SW1/4 0.64 Muddy Cr

CC81/089 09/07/1995 -- USDI BLM Muddy Creek Duck Pond Ditch RES 016N 092W 5 -- 159 Muddy Cr

CR14/241 09/07/1995 -- USDI BLM Upper Dike Reservoir WET 016N 092W 5 -- 2.00 Muddy Cr

CR14/242 09/07/1995 -- USDI BLM Middle Dike Reservoir WET 016N 092W 5 -- 2.00 Muddy CrCR14/243 09/07/1995 -- USDI BLM Lower Dike Reservoir WET 016N 092W 5 SW1/4SW1/4 4.00 Muddy CrP11760R 05/27/2004 Unadjudicated -- Duck Pond #5 Reservoir 

FIS; STO; 

WET; 

COMBBU 

016N 092W 8 -- -- Muddy Cr

P17154S 07/08/1994 Unadjudicated -- LSRCD/Weber Pit #1 (West) Stock Reservoir STO 016N 092W 8 -- -- Muddy Cr

P17155S 07/08/1994 Unadjudicated -- LSRCD/Weber Pit #2 (East) Stock Reservoir STO 016N 092W 8 -- -- Muddy Cr

P6871S 01/25/1971 Fully Adjudicated USDI BLM Cedar Stock Reservoir STO 016N 092W 9 NE1/4NE1/4 0.86 South CedaCR07/240 01/25/1971 -- USDI BLM Cedar Stock Reservoir STO 016N 092W 9 NE1/4NE1/4 0.86 South CedaP11331S 09/04/1991 -- -- Juniper Ridge Stock Reservoir STO 016N 092W 10 NE1/4NE1/4 0.23 Dry Cow C

P11834D 11/17/1904 Unadjudicated 

A.T. CORLETT Corlett Ditch IRR; STO 016N 092W 17 NE1/4NW1/4 3.78 Muddy Cr

P7754D 03/29/1907 Fully Adjudicated Stephen Adams Muddy Ditch IRR 016N 092W 20 SE1/4NE1/4 3.15 Muddy Cr

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P11027S 06/04/1990 -- -- Irrigation Ditch Stock Reservoir STO 016N 092W 21 NW1/4SW1/4 0.15 East Fork M

Creek 

P18716S 10/25/2007 Complete PATRICK AND JUDITH SHEEHAN PS-3 STOCK RESERVOIR STO 016N 092W 28 -- -- PS-3 Dra

P10548R 07/22/1997 Fully Adjudicated -- Red Wash #1 Wetland Reservoir FIS; STO; WET; COMBBU 016N 092W 29 SE1/4SW1/4 39.68 Little Snake 

P7195E 07/08/1997 Fully Adjudicated -- RED WASH L.H. enl Muddy Ditch FIS; RES 016N 092W 29 -- 3.61 Muddy CrCR15/279 07/22/1997 -- City of Cheyenne, et al. Red Wash No. 1 Wetland Reservoir FIS; STO; WET 016N 092W 29 SE1/4SW1/4 39.68 Little Snake 

P9620S 03/25/1985 Fully Adjudicated -- Adobe Cove Pit Stock Reservoir STO 016N 092W 30 SE1/4NE1/4 0.75 Flats Dra

CR11/092 03/25/1985 -- USDI BLM 

Adobe Cove Pit Stock 

Reservoir STO 016N 092W 30 SE1/4NE1/4 0.75 Flats Dra

P10549R 07/22/1997 Fully Adjudicated -- Red Wash #4 Wetland Reservoir FIS; STO; WET; COMBBU 016N 092W 31 NE1/4NE1/4 21.4 Flats Dra

CR15/280 07/22/1997 -- City of Cheyenne, et al. Red Wash No. 4 Wetland Reservoir FIS; STO; WET 016N 092W 31 NE1/4NE1/4 21.4 Flats Dra

P10546R 07/08/1997 Fully Adjudicated -- Red Wash #2 Wetland Reservoir FIS; STO; WET; COMBBU 016N 092W 32 SW1/4NE1/4 143.36 Little Snake 

P10547R 07/08/1997 Fully Adjudicated -- Red Wash #3 Wetland Reservoir FIS; STO; WET; COMBBU 016N 092W 32 SW1/4NE1/4 8.10 Little Snake 

P11367R 05/31/2002 Unadjudicated -- RED WASH #5 WETLAND Reservoir FIS; STO; WET; COMBBU 016N 092W 32 SE1/4NE1/4 -- Muddy Cr

P7346E 05/31/2002 Unadjudicated USDI BLM RED WASH SECOND ENL. MUDDY DITCH (#7754) FTH; RES 016N 092W 32 NE1/4NE1/4 -- Muddy Cr

CR15/277 07/08/1997 -- City of Cheyenne, et al. Red Wash No. 2 Wetland Reservoir FIS; STO; WET 016N 092W 32 SW1/4NE1/4 143.36 Little Snake 

CR15/278 07/08/1997 -- City of Cheyenne, et al. Red Wash No. 3 Wetland Reservoir FIS; STO; WET 016N 092W 32 SW1/4NE1/4 8.10 Little Snake 

P11029S 06/04/1990 -- -- Northwest Border Stock Reservoir STO 016N 092W 34 NW1/4NW1/4 1.37 Northwest B

Draw 

P12671S 11/08/1995 -- -- Niland No. 1 (5521) Stock Reservoir STO 016N 092W 35 NW1/4SE1/4 0.36 Muddy Cr

CC82/147 07/08/1997 -- City of Cheyenne, Board of Public Utilities, et al. Muddy Ditch,, Enl. RES 016N 092W -- 212.00 Muddy Cr

P10867S 01/24/1990 Unadjudicated -- Clay Flat Stock Reservoir STO 016N 093W 1 NE1/4NW1/4 1.29 Doty Dra

F-8 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P9621S 03/25/1985 Fully Adjudicated -- No. Barrel Springs Pit Stock Reservoir STO 016N 093W 9 NW1/4NW1/4 0.74 Red Dra

CR11/094 03/25/1985 -- USDI BLM No. Barrel Springs Pit Stock Reservoir STO 016N 093W 9 NW1/4NW1/4 0.74 Red DraP12702R 10/31/2005 Complete DOUBLE EAGLE PETROLEUM CO. LSRCD SECTION 13 RESERVOIR 016N 093W 13 NE1/4NW1/4 -- Blue Eagle 

P10521S 12/19/1988 -- -- Lower Windmill STO 016N 093W 17 NE1/4SW1/4 0.15 Folly Dra

P6914S 01/25/1971 Fully Adjudicated USDI BLM Mexican Flats No. 2 Stock Reservoir STO 016N 093W 17 NW1/4NE1/4 1.3 Herder D

CR06/160 01/25/1971 -- USDI BLM Mexican Flats No. 2 Stock Reservoir STO 016N 093W 17 NW1/4NE1/4 1.3 Herder D

P10523S 12/19/1988 -- -- Mexican Graves Stock Reservoir STO 016N 093W 19 SE1/4NW1/4 2.78 Herder D

P6573S 12/10/1969 Fully Adjudicated USDI BLM Mexican Flats No. 3 Stock Reservoir STO 016N 093W 22 NE1/4NE1/4 1.68 Tick Dra

CR05/597 12/10/1969 -- USDI BLM Mexican Flats No. 3 Stock Reservoir STO 016N 093W 22 NE1/4NE1/4 1.68 Tick Dra

P9622S 03/25/1985 Fully Adjudicated -- Lone Pit Stock Reservoir STO 016N 093W 25 SE1/4SE1/4 3.23 Barrel Spring

CR11/090 03/25/1985 -- USDI BLM Lone Pit Stock Reservoir STO 016N 093W 25 SE1/4SE1/4 3.23 Barrel Spring

P6572S 12/10/1969 Fully Adjudicated USDI BLM Mexican Flats No. 1 Stock Reservoir STO 016N 093W 29 NE1/4SE1/4 1.30 Beatle Dr

CR05/596 12/10/1969 -- USDI BLM Mexican Flats No. 1 Stock Reservoir STO 016N 093W 29 NE1/4SE1/4 1.30 Beatle Dr

P11316S 09/11/1991 -- -- Mexican Flats Stock Reservoir STO 016N 093W 33 SW1/4SE1/4 8.81 Mexican Flat

P11340S 09/04/1991 -- -- South Border Stock Reservoir STO 016N 093W 35 NW1/4SW1/4 2.34 South Barrel 

Draw 

P9623S 03/25/1985 Fully Adjudicated -- Barrel Spings Draw Pit Stock Reservoir STO 016N 094W 12 SE1/4SW1/4 0.74 Barrel Spring

CR11/093 03/25/1985 -- USDI BLM Barrel Springs Draw Pit Stock Reservoir STO 016N 094W 12 SE1/4SW1/4 0.74 Barrel Spring

P11360S 09/09/1991 -- -- Windmill Draw Stock Reservoir STO 016N 094W 25 NE1/4NW1/4 2.34 Herder D

P10564S 12/29/1988 -- -- Pit 1694 #1 Stock Reservoir STO 016N 094W 27 NE1/4SE1/4 0.86 Wild Rube 

P11062S 08/09/1990 -- -- Crosby Stock Reservoir STO 016N 095W 27 NW1/4NE1/4 2.14 Willow Dr

P4904S 12/16/1963 Fully Adjudicated P.S.(SID) WEBER West Fork No. 3 Stock Reservoir STO 017N 091W 19 SW1/4SE1/4 1.17 Broken Hitch 

CR05/034 12/16/1963 -- P.S. (SID) WEBER West Fork No. 3 Stock Reservoir STO 017N 091W 19 SW1/4SE1/4 1.17 Broken Hitch 

P17152S 07/08/1994 Unadjudicated -- Washakie Stock Reservoir STO 017N 092W 5 SW1/4NE1/4 -- Washakie 

P10710S 05/17/1989 -- -- Quit Claim Stock Reservoir STO 017N 092W 8 SE1/4NW1/4 3.19 Quit Dra

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P12672S 11/08/1995 -- -- Pine Butte (5309) Stock Reservoir STO 017N 092W 10 NE1/4SW1/4 3.29 Antelope C

P25633D 01/21/1977 Unadjudicated Steve F. Adams 

Adams Portable Pump 

Irrigation System No. 1 IRR 017N 092W 14 NE1/4NW1/4 0.48 Muddy Cr

P25634D 01/21/1977 Fully Adjudicated Steve F. Adams 

Adams Portable Pump 

Irrigation System #2 IRR 017N 092W 15 SE1/4NE1/4 0.21 Muddy Cr

P25635D 01/21/1977 Fully Adjudicated Steve F. Adams 

Adams Portable Pump 

Irrigation System No. 3 IRR 017N 092W 15 NW1/4SE1/4 0.43 Muddy Cr

P25636D 01/21/1977 Fully Adjudicated Steve F. Adams 

Adams Portable Pump 

Irrigation System # 4 IRR 017N 092W 15 SE1/4SW1/4 0.44 Muddy Cr

CC73/279 01/21/1977 -- HERBERT H. KOHL 

Adams Portable Pump 

Irrigation System #2 IRR 017N 092W 15 SE1/4NE1/4 0.21 Muddy Cr

CC73/280 01/21/1977 -- HERBERT H. KOHL 

Adams Portable Pump 

Irrigation System No. 3 IRR 017N 092W 15 NW1/4SE1/4 0.44 Muddy Cr

CC73/281 01/21/1977 -- HERBERT H. KOHL 

Adams Portable Pump 

Irrigation System # 4 IRR 017N 092W 15 SE1/4SW1/4 0.45 Muddy Cr

P11159S 11/01/1990 Fully Adjudicated Weber Ranch Inc. Tree Stock Reservoir STO 017N 092W 19 SW1/4NW1/4 4.40 Little Coal G

CR13/215 11/01/1990 WEBER RANCH COMPANY Tree Stock Reservoir STO 017N 092W 19 SW1/4NW1/4 4.40 Little Coal G

P11011S 07/12/1990 Unadjudicated -- South Baldy Butte Stock Reservoir STO 017N 092W 20 SW1/4SE1/4 2.43 Baldy DrP11012S 07/12/1990 Unadjudicated -- West Doty #5 Stock Reservoir STO 017N 092W 20 SW1/4SE1/4 1.43 Doty No. 2 

P11158S 11/01/1990 Fully Adjudicated -- Salisbury Stock Reservoir STO 017N 092W 25 SW1/4NE1/4 3.32 Phillip Dr

CR13/214 11/01/1990 -- SAM SCOTT, ET AL. Salisbury Stock Reservoir STO 017N 092W 25 SW1/4NE1/4 3.32 Phillip Dr

P794S 04/01/1954 Unadjudicated -- Cedar Draw Pit Stock Reservoir STO 017N 092W 33 SW1/4SW1/4 6.08 Cedar Dr

P11061S 08/09/1990 -- -- Electric Well Stock Reservoir STO 017N 092W 34 NE1/4NE1/4 1.64 Upper Electr

Draw 

P10560S 12/29/1988 -- -- West Doty No. 4 Stock Reservoir STO 017N 093W 10 SW1/4SE1/4 16.10 Swigger D

P10525S 12/19/1988 -- -- Big Flat Stock Reservoir STO 017N 093W 12 SE1/4SE1/4 0.39 Cloverleaf Rid

P1051S 01/11/1955 -- EUREKA SHEEP CO. Eureka #7 Stock Reservoir STO 017N 093W 17 SW1/4NW1/4 2.74 North Barrel S

P10522S 12/19/1988 -- -- LaClede No. 2 Stock Reservoir STO 017N 093W 26 SE1/4SW1/4 1.18 Barrell Spring

P11013S 07/12/1990 Unadjudicated -- West Doty #2 Stock Reservoir STO 017N 093W 36 NE1/4NE1/4 17.7 Big Doty D

P10338S 10/08/1987 -- -- Adam's Pit No. 1 Stock Reservoir STO 017N 094W 6 SE1/4NW1/4 3.12 North Barrel S

Draw 

F-10 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P12670S 11/08/1995 -- -- Overland #1 (0272) Stock Reservoir STO 017N 094W 14 SW1/4SW1/4 1.38 North Barrel S

Draw 

P7716S 06/26/1974 Fully Adjudicated USDI BLM Barrel (Index #4370) Stock Reservoir STO 017N 095W 2 NW1/4NE1/4 4.43 North Barrel S

Draw 

CR08/525 06/26/1974 -- USDI BLM Barrel (Index #4370) Stock Reservoir STO 017N 095W 2 NW1/4NE1/4 4.43 North Barrel S

Draw 

P10350S 12/07/1987 -- -- Pit 1795 A Stock Reservoir STO 017N 095W 14 SE1/4NW1/4 0.3 Little Rose 

P7776S 06/26/1974 Fully Adjudicated USDI BLM Boy (Index #4367) Stock Reservoir STO 017N 095W 16 NE1/4NW1/4 5.51 Wild Rose 

CR08/529 06/26/1974 USDI BLM Boy (Index #4367) Stock Reservoir STO 017N 095W 16 NE1/4NW1/4 5.51 Wild Rose 

P10869S 01/24/1990 Unadjudicated -- 1795 B Stock Reservoir STO 017N 095W 22 NE1/4SE1/4 0.87 Trail Wa

P7775S 06/26/1974 Fully Adjudicated USDI BLM Little Draw (Index #4368) Stock Reservoir STO 017N 095W 36 SW1/4NW1/4 2.84 Mulligan D

CR08/528 06/26/1974 -- USDI BLM Little Draw (Index #4368) Stock Reservoir STO 017N 095W 36 SW1/4NW1/4 2.84 Mulligan D

P9774S 09/27/1985 Fully Adjudicated -- Badwater #6 Stock Reservoir STO 018N 091W 6 NE1/4NE1/4 19.76 Bad Water C

CR11/067 09/27/1985 -- USDI BLM Badwater #6 Stock Reservoir STO 018N 091W 6 19.76 Bad Water C

P10131S 03/02/1981 Unadjudicated Niels Hansen P. H. Fourteen Stock Reservoir STO 018N 091W 11 NE1/4NE1/4 2.69 PH Fourteen 

P9755S 09/12/1985 Fully Adjudicated -- Badwater #7 Stock Reservoir STO 018N 091W 18 NE1/4SE1/4 2.28 Holler Dr

CR11/087 09/12/1985 -- USDI BLM Badwater #7 Stock Reservoir STO 018N 091W 18 NE1/4SE1/4 2.28 Holler Dr

P11355S 09/09/1991 -- -- Badwater #8 Stock Reservoir STO 018N 091W 20 SE1/4SW1/4 1.37 South Divide 

P10132S 03/02/1981 Unadjudicated Niels Hansen Chicken Springs Stock Reservoir STO 018N 091W 21 SW1/4SE1/4 0.59 Chicken Sprin

P11070S 09/06/1990 -- -- Badwater #10 Stock Reservoir STO 018N 091W 22 SW1/4SW1/4 0.48 Chicken Sprin

P11069S 09/06/1990 -- -- Badwater #11 Stock Reservoir STO 018N 091W 28 SE1/4NW1/4 0.71 Lower Chicken 

Wash 

P11074S 09/06/1990 -- -- Badwater #13 Stock Reservoir STO 018N 091W 30 SE1/4SE1/4 1.93 Upper Badwat

P11356S 09/09/1991 -- -- Badwater #14 Stock Reservoir STO 018N 091W 30 SE1/4NE1/4 0.07 Upper BadwatP10713S 05/17/1989 -- -- Sugar Loaf Stock Reservoir STO 018N 092W 4 NW1/4SW1/4 0.67 SUGAR W

P6712S 04/27/1970 Fully Adjudicated USDI BLM Continental Stock Reservoir STO 018N 092W 12 NE1/4NE1/4 2.21 Fan Dra

CR06/131 04/27/1970 -- USDI BLM Continental Stock Reservoir STO 018N 092W 12 NE1/4NE1/4 2.21 Fan Dra

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P8949S 10/16/1981 Fully Adjudicated -- 13-18-92 No. 1 Stock Reservoir STO 018N 092W 13 SW1/4NW1/4 0.78 West Fork Hol

CR09/297 10/16/1981 -- DOM ECHEVERRIA TRUST 13-18-92 No. 1 Stock Reservoir STO 018N 092W 13 SW1/4NW1/4 0.78 West Fork Hol

P8947S 10/16/1981 Fully Adjudicated -- 15-18-92 No. 2 Stock Reservoir STO 018N 092W 15 SW1/4NW1/4 1.32 Echeverria 

P8948S 10/16/1981 Fully Adjudicated -- 15-18-92 No. 1 Stock Reservoir STO 018N 092W 15 SE1/4SE1/4 2.80 South Fork CoCR09/294 10/16/1981 -- DOM ECHEVERRIA TRUST 15-18-92 No. 1 Stock Reservoir STO 018N 092W 15 SE1/4SE1/4 2.80 South Fork CoCR09/295 10/16/1981 -- DOM ECHEVERRIA TRUST 15-18-92 No. 2 Stock Reservoir STO 018N 092W 15 SW1/4NW1/4 1.32 Echeverria 

P10780S 05/17/1989 -- -- South Echo #4 Stock Reservoir STO 018N 092W 18 NE1/4NE1/4 0.30 North Divide 

P8945S 10/16/1981 Fully Adjudicated -- 21-18-92 No. 1 Stock Reservoir STO 018N 092W 21 SW1/4NW1/4 0.22 South Fork CoCR09/293 10/16/1981 -- DOM ECHEVERRIA TRUST 21-18-92 No. 1 Stock Reservoir STO 018N 092W 21 SW1/4NW1/4 0.22 South Fork Co

P10711S 05/17/1989 -- -- Upper Coal Gulch Stock Reservoir STO 018N 092W 22 NW1/4NW1/4 1.52 South Fork Co

P9758S 09/12/1985 Fully Adjudicated -- Double Cove Stock Reservoir STO 018N 092W 26 SW1/4NE1/4 3.02 Double C

CR11/086 09/12/1985 -- USDI BLM Double Cove Stock Reservoir STO 018N 092W 26 SW1/4NE1/4 3.02 Double C

P10559S 12/29/1988 -- -- South Echo No. 2 Stock Reservoir STO 018N 092W 28 SW1/4SE1/4 3.48 Echo Dra

P8944S 10/16/1981 Fully Adjudicated -- 29-18-92 No. 1 Stock Reservoir STO 018N 092W 29 SE1/4SW1/4 0.37 Sage Chicke

CR09/292 10/16/1981 -- DOM ECHEVERRIA TRUST 29-18-92 No. 1 Stock Reservoir STO 018N 092W 29 SE1/4SW1/4 0.37 Sage Chicke

P11109S 08/23/1990 -- -- South Echo #1 Stock Reservoir STO 018N 092W 30 SE1/4SE1/4 2.45 Upper Echo 

P9782S 09/27/1985 Fully Adjudicated -- Upper Soap Hole Stock Reservoir STO 018N 092W 34 SE1/4NE1/4 7.21 Soap Hole W

CR11/085 09/27/1985 -- USDI BLM Upper Soap Hole Stock Reservoir STO 018N 092W 34 SE1/4NE1/4 7.21 Soap Hole W

P10779S 05/17/1989 -- -- Lower Coal Bank Stock Reservoir STO 018N 093W 10 SE1/4SW1/4 2.45 Lower Coal 

Wash 

P8951S 10/16/1981 Fully Adjudicated -- 11-18-93 No. 1 Stock Reservoir STO 018N 093W 11 SW1/4NE1/4 0.96 Coal Bank W

CR09/274 10/16/1981 -- DOM ECHEVERRIA TRUST 11-18-93 No. 1 Stock Reservoir STO 018N 093W 11 SW1/4NE1/4 0.96 Coal Bank W

F-12 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P5245R 02/10/1940 Fully Adjudicated US DEPARTMENT OF INTERIOR, DIV. OF GRAZING Government No. 1 Reservoir STO 018N 093W 17 SE1/4NE1/4 98.57 Government D

1 

CR12/366 02/10/1940 -- USDI BLM Government No. 1 Reservoir STO 018N 093W 17 SE1/4NE1/4 98.57 Government D

1 

P8515S 09/12/1978 Fully Adjudicated Union Pacific Railroad Elwood Stock Reservoir STO 018N 093W 21 NE1/4NE1/4 2.60 Government D

1 

CR08/612 09/12/1978 -- STEVE F. ADAMS Elwood Stock Reservoir STO 018N 093W 21 NE1/4NE1/4 2.60 Government D

1 

P8950S 10/16/1981 Fully Adjudicated -- 25-18-93 No. 1 Stock Reservoir STO 018N 093W 25 SW1/4SE1/4 0.53 Sheephead 

CR09/296 10/16/1981 -- DOM ECHEVERRIA TRUST 25-18-93 No. 1 Stock Reservoir STO 018N 093W 25 SW1/4SE1/4 0.53 Sheephead 

P10699S 03/31/1989 -- -- Coal Gulch No. 2 Stock Reservoir STO 018N 093W 26 SW1/4SW1/4 0.94 Barrell Spring

P7760S 06/26/1974 Fully Adjudicated USDI BLM Twelvemile (Index #4318) Stock Reservoir STO 018N 093W 30 NW1/4NE1/4 3.56 Coal Bank La

CR08/480 06/26/1974 -- USDI BLM Twelvemile (Index #4318) Stock Reservoir STO 018N 093W 30 NW1/4NE1/4 3.56 Coal Bank La

P7741S 06/26/1974 Fully Adjudicated USDI BLM Red Lake (Index #4342) Stock Reservoir STO 018N 094W 8 NE1/4NE1/4 3.22 Corral Dr

CR08/080 06/26/1974 -- USDI BLM Red Lake (Index #4342) Stock Reservoir STO 018N 094W 8 NE1/4NE1/4 3.22 Corral Dr

P10333S 10/05/1987 -- -- Adam's Pit No. 2 Stock Reservoir STO 018N 094W 20 NW1/4SW1/4 2.25 RED MIRAGE 

P7777S 06/26/1974 Fully Adjudicated USDI BLM Stratton NW (Index #4365) Stock Reservoir STO 018N 095W 6 SW1/4NW1/4 3.47 Upper Rim CR08/527 06/26/1974 -- USDI BLM Stratton NW (Index #4365) Stock Reservoir STO 018N 095W 6 SW1/4NW1/4 3.47 Upper Rim 

P7745S 06/26/1974 Fully Adjudicated USDI BLM Two Draw (Index #4366) Stock Reservoir STO 018N 095W 8 SW1/4SE1/4 19.45 Upper Rim CR08/526 06/26/1974 -- USDI BLM Two Draw (Index #4366) Stock Reservoir STO 018N 095W 8 SW1/4SE1/4 19.45 Upper Rim 

P7750S 06/26/1974 Fully Adjudicated USDI BLM Delaney Rim (Index #4369) Stock Reservoir STO 018N 095W 26 SW1/4NW1/4 2.39 East Wa

CR08/530 06/26/1974 -- USDI BLM Delaney Rim (Index #4369) Stock Reservoir STO 018N 095W 26 SW1/4NW1/4 2.39 East Wa

P3834S 11/27/1961 Unadjudicated P H Livestock Co. Hansen Stock Reservoir STO 018N 096W 9 SW1/4SW1/4 1.78 Bitter Creek (d

of) 

P7780S 06/26/1974 Fully Adjudicated USDI BLM Rabbit Brush (Index #4349) Stock Reservoir STO 018N 096W 10 NE1/4SE1/4 2.98 Rabbit Brush 

CR08/532 06/26/1974 -- USDI BLM Rabbit Brush (Index #4349) Stock Reservoir STO 018N 096W 10 NE1/4SE1/4 2.98 Rabbit Brush 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P4387S 08/22/1961 Incomplete -- DALEY DAM STOCK RESERVOIR STO 018N 096W 18 SE1/4NW1/4 8.70 Bitter Creek (d

of) 

P12969S 10/17/1997 Fully Adjudicated PH Livestock Co. Barrel Springs Stock Reservoir STO 018N 096W 25 SW1/4NE1/4 4.03 Hansen DCR15/218 10/17/1997 -- PH Livestock Company Barrel Springs Stock Reservoir STO 018N 096W 25 SW1/4NE1/4 4.03 Hansen D

P7740S 06/26/1974 Fully Adjudicated USDI BLM Rocky Point (Index #4348) Stock Reservoir STO 018N 096W 30 SW1/4SE1/4 2.98 Laney Wa

CR08/075 06/26/1974 -- USDI BLM Rocky Point (Index #4348) Stock Reservoir STO 018N 096W 30 SW1/4SE1/4 2.98 Laney WaP12968S 10/17/1997 Fully Adjudicated PH Livestock Co. PH Man & Boy Stock Reservoir STO 018N 096W 35 SE1/4NE1/4 4.03 Ph Draw 

P7779S 06/26/1974 Fully Adjudicated USDI BLM Man and The Boy (Index #4350) Stock Reservoir STO 018N 096W 36 NW1/4NE1/4 2.95 Man and the BCR08/531 06/26/1974 -- USDI BLM Man and The Boy (Index #4350) Stock Reservoir STO 018N 096W 36 NW1/4NE1/4 2.95 Man and the BUW03/071 01/22/1974 Fully Adjudicated THE TEXAS COMPANY TABLE ROCK UNIT WATER WELL NO. 5 MIS 018N 098W 1 NW1/4NE1/4 13.0 -- 

P10675S 03/31/1989 -- -- Horse Butte Stock Reservoir STO 019N 091W 6 SE1/4NE1/4 0.95 No Job DrP10136S 03/02/1981 Unadjudicated Niels Hansen PH Twelve Stock Reservoir STO 019N 091W 25 SW1/4SE1/4 0.45 PH Twelve 

P11346S 09/09/1991 -- -- Fillmore Bend Stock Reservoir STO 019N 091W 26 SE1/4NW1/4 2.57 Fillmore C

P11312S 09/11/1991 -- -- Badwater #3 Stock Reservoir STO 019N 091W 30 SW1/4SW1/4 2.29 North Divide 

P11347S 09/09/1991 Unadjudicated -- Badwater #5 Stock Reservoir STO 019N 091W 32 NW1/4SW1/4 1.09 Bad Water C

P10137S 03/02/1981 Unadjudicated Niels Hansen Fillmore Creek Stock Reservoir STO 019N 091W 35 SW1/4SE1/4 1.38 Fillmore C

P11348S 09/09/1991 -- -- Lazy YS Stock Reservoir STO 019N 092W 4 NW1/4NW1/4 0.37 County Line 

P12162S 08/25/1994 Fully Adjudicated Duane & Deborah Rodewald Section 11 Stock Reservoir STO 019N 092W 11 NW1/4NE1/4 0.08 Separation 

CR14/215 08/25/1994 -- THOMAS F DAVENPORT, JR. Section 25 East Stock Reservoir STO 019N 092W 11 NW1/4NE1/4 0.08 Rodewald 

P7467R 06/21/1972 Unadjudicated -- Seaverson Reservoir 

FIS; REC; 

STO; 

COMBBU 

019N 092W 24 NW1/4NE1/4 335.8 FILLMORE/FI

CREEK 

P12163S 08/25/1994 Fully Adjudicated Duane & Deborah Rodewald Section 25 East Stock Reservoir STO 019N 092W 25 SE1/4NE1/4 0.08 Rodewald 

P12164S 08/25/1994 Fully Adjudicated Duane & Deborah Rodewald Section 25 West Stock Reservoir STO 019N 092W 25 SE1/4NE1/4 0.08 Rodewald 

CR14/216 08/25/1994 -- THOMAS F DAVENPORT, JR. Section 25 West Stock Reservoir STO 019N 092W 25 SE1/4NE1/4 0.08 Rodewald 

F-14 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P12165S 08/25/1994 Fully Adjudicated Duane & Deborah Rodewald Section 35 East Stock Reservoir STO 019N 092W 35 NE1/4SE1/4 0.08 Separation 

P12166S 08/25/1994 Fully Adjudicated Duane & Deborah Rodewald Section 35 West Stock Reservoir STO 019N 092W 35 SW1/4NE1/4 0.08 Separation 

CR14/217 08/25/1994 -- THOMAS F DAVENPORT, JR. Section 35 East Stock Reservoir STO 019N 092W 35 NE1/4SE1/4 0.08 Separation 

CR14/218 08/25/1994 -- THOMAS F DAVENPORT, JR. Section 35 West Stock Reservoir STO 019N 092W 35 SW1/4NE1/4 0.08 Separation 

P6715S 04/27/1970 Fully Adjudicated USDI BLM Northwest Echo Stock Reservoir STO 019N 093W 6 NW1/4NE1/4 3.18 Dry Lake CR06/134 04/27/1970 -- USDI BLM Northwest Echo Stock Reservoir STO 019N 093W 6 NW1/4NE1/4 3.18 Dry Lake 

P6713S 04/27/1970 Fully Adjudicated USDI BLM East Echo Stock Reservoir STO 019N 093W 14 SE1/4SE1/4 2.84 Echo Springs 

CR06/132 04/27/1970 -- USDI BLM East Echo Stock Reservoir STO 019N 093W 14 SE1/4SE1/4 2.84 Echo Springs 

P11127R 04/12/2001 Unadjudicated Samson Resources Co. Crystal Solutions FTE Reservoir IND; IRR; STO; COMBBU 019N 093W 19 SW1/4SE1/4 -- Adams D

P12785R 11/24/2006 Complete SAMSON RESOURCES HOLDING POND 5-6 RESERVOIR IND 019N 093W 19 NW1/4SE1/4 -- Adams D

P6714S 04/27/1970 Fully Adjudicated USDI BLM West Echo Stock Reservoir STO 019N 093W 20 SE1/4SE1/4 2.97 Echo Springs 

CR06/133 04/27/1970 -- USDI BLM West Echo Stock Reservoir STO 019N 093W 20 SE1/4SE1/4 2.97 Echo Springs 

P10877S 01/24/1990 -- -- Horse Pasture Draw Stock Reservoir STO 019N 093W 26 NE1/4SW1/4 2.51 Horse Pastur

P8521S 09/25/1978 Fully Adjudicated Stephen L. Adams Adams #1B Stock Reservoir STO 019N 093W 31 SE1/4NW1/4 2.71 Standard DCR10/214 09/25/1978 -- STEVE F. ADAMS 

Adams #1B Stock Reservoir STO 019N 093W 31 SE1/4NW1/4 2.71 Standard D

P11367S 09/09/1991 -- -- West 44 - Echo Stock Reservoir STO 019N 093W 36 NE1/4NE1/4 0.36 Standard DP8046S 10/16/1975 Fully Adjudicated -- Wamsutter Stock Reservoir STO 019N 094W 3 NE1/4SW1/4 2.34 LATHAM D

CR08/435 10/16/1975 -- UNION PACIFIC LAND RESOURCES CORP Wamsutter Stock Reservoir STO 019N 094W 3 NE1/4SW1/4 2.34 LATHAM D

P8045S 10/16/1975 Fully Adjudicated -- Frewen Stock Reservoir STO 019N 094W 5 NW1/4SW1/4 2.66 FREWEN D

CR08/478 10/16/1975 -- UNION PACIFIC LAND RESOURCES CORP Frewen Stock Reservoir STO 019N 094W 5 NW1/4SW1/4 2.66 FREWEN D

P8523S 09/25/1978 Fully Adjudicated Steve F. Adams Adams #1D Stock Reservoir STO 019N 094W 9 NE1/4SW1/4 2.66 Cecil Dra

CR10/215 09/25/1978 -- STEVE F. ADAMS 

Adams #1D Stock Reservoir STO 019N 094W 9 NE1/4SW1/4 2.66 Cecil Dra

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P8522S 09/25/1978 Fully Adjudicated Steve F. Adams Adams #1C Stock Reservoir STO 019N 094W 11 NW1/4SE1/4 2.66 Esther Dr

CR10/213 09/25/1978 -- STEVE F. ADAMS 

Adams #1C Stock Reservoir STO 019N 094W 11 NW1/4SE1/4 2.66 Esther Dr

P10527R 05/05/1997 Unadjudicated -- Wamsutter Saltwater Disposal No. 2 Reservoir IND; TEM; COMBBU 019N 094W 13 NW1/4NW1/4 420 Dry Lake 

P8524S 09/25/1978 Fully Adjudicated Steve F. Adams Adams #1E Stock Reservoir STO 019N 094W 19 NW1/4NE1/4 2.66 Jody Dra

CR10/216 09/25/1978 -- STEVE F. ADAMS 

Adams #1E Stock Reservoir STO 019N 094W 19 NW1/4NE1/4 2.66 Jody Dra

P11370S 09/09/1991 Fully Adjudicated -- South Wamsutter Stock Reservoir STO 019N 094W 22 NE1/4SW1/4 2.49 South Wamsu

Draw 

CR13/191 09/09/1991 -- USDI BLM South Wamsutter Stock Reservoir STO 019N 094W 22 NE1/4SW1/4 2.49 South Wamsu

Draw 

P11368S 09/09/1991 Fully Adjudicated -- Dry Lake Stock Reservoir STO 019N 094W 26 SE1/4SE1/4 1.79 Spring Pit D

CR13/190 09/09/1991 -- USDI BLM Dry Lake Stock Reservoir STO 019N 094W 26 SE1/4SE1/4 1.79 Spring Pit D

P9111D 06/07/1909 -- Rasmusson Sheep Co. Rasmussen Ditch No. 1 IRR; STO 019N 095W 4 SW1/4SW1/4 1.31 Un-named C

UW03/473 07/10/1972 Fully Adjudicated MOYER'S SERVICE MOYER NO. 1 WELL MIS 019N 095W 4 SW1/4NW1/4 10.00 

P15320D 12/29/1918 Unadjudicated Rasmusson Sheep Co. Supply Ditch IRR; STO 019N 095W 5 SE1/4SE1/4 Red Wash 

P9112D 06/07/1909 -- Rasmusson Sheep Co. Rasmussen Ditch No. 2 IRR; STO 019N 095W 5 SW1/4NE1/4 6.71 Un-named C

P9113D 06/07/1909 -- Rasmusson Sheep Co. Rasmussen Ditch No. 3 IRR; STO 019N 095W 5 SW1/4NE1/4 12.99 NAMING ER

P8044S 10/16/1975 Fully Adjudicated Steve F. Adams Wamsutter Rim Stock Reservoir STO 019N 095W 11 NW1/4SE1/4 2.66 WAMSUTTER 

CR08/434 10/16/1975 -- STEVE F. ADAMS Wamsutter Rim Stock Reservoir STO 019N 095W 11 NW1/4SE1/4 2.66 WAMSUTTER 

P8043S 10/16/1975 Fully Adjudicated Steve F. Adams Red Lake Stock Reservoir STO 019N 095W 15 NE1/4SE1/4 2.66 Red Dra

CR08/433 10/16/1975 -- STEVE F. ADAMS Red Lake Stock Reservoir STO 019N 095W 15 NE1/4SE1/4 2.66 Red DraP7763S 06/26/1974 Fully Adjudicated USDI BLM East Red Draw (Index #4345) Stock Reservoir STO 019N 095W 18 NE1/4NW1/4 3.22 MIDDLE RED 

P9795S 10/28/1985 Fully Adjudicated -- Lower Red Draw Stock Reservoir STO 019N 095W 18 NW1/4NE1/4 5.87 Middle Red CR11/457 10/28/1985 -- USDI BLM Lower Red Draw Stock Reservoir STO 019N 095W 18 NW1/4NE1/4 5.87 Middle Red 

CR08/077 06/26/1974 -- USDI BLM East Red Draw (Index #4345) Stock Reservoir STO 019N 095W 18 NE1/4NW1/4 3.22 MIDDLE RED P10878S 01/24/1990 -- -- Powerline Pit Stock Reservoir STO 019N 095W 20 NW1/4NE1/4 1.38 Powerline W

P7753S 06/26/1974 Fully Adjudicated USDI BLM Northeast Point (Index #4343) Stock Reservoir STO 019N 095W 20 NW1/4SW1/4 4.26 West Fork No

Wash 

CR08/316 06/26/1974 -- USDI BLM Northeast Point (Index #4343) Stock Reservoir STO 019N 095W 20 NW1/4SW1/4 4.26 West Fork No

Wash 

F-16 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P9794S 10/28/1985 -- -- Jolley Stock Reservoir STO 019N 095W 28 SE1/4SE1/4 1.54 Wells Bluff 

P7754S 06/26/1974 Fully Adjudicated USDI BLM Tortilla (Index #4344) Stock Reservoir STO 019N 095W 30 NW1/4NW1/4 2.03 Tortilla D

CR08/078 06/26/1974 -- USDI BLM Tortilla (Index #4344) Stock Reservoir STO 019N 095W 30 NW1/4NW1/4 2.03 Tortilla D

P7742S 06/26/1974 Fully Adjudicated USDI BLM Red Flat (Index #4341) Stock Reservoir STO 019N 095W 36 NW1/4SW1/4 2.98 Confusion 

CR08/081 06/26/1974 -- USDI BLM Red Flat (Index #4341) Stock Reservoir STO 019N 095W 36 NW1/4SW1/4 2.98 Confusion 

UW04/458 11/10/1977 -- PANHANDLE EASTERN PIPE LINE COMPANY Tipton Compressor No. 1 Well MIS 019N 096W 7 NW1/4NE1/4 5.00 -- UW04/459 04/09/1984 -- PANHANDLE EASTERN PIPE LINE COMPANY Tipton Compressor No. 1 Well,, Enl. MIS 019N 096W 7 NW1/4NE1/4 0.00 -- P7765S 06/26/1974 Fully Adjudicated USDI BLM West Red Draw (Index #4347) Stock Reservoir STO 019N 096W 22 SE1/4SE1/4 3.62 West Red 

CR08/079 06/26/1974 -- USDI BLM West Red Draw (Index #4347) Stock Reservoir STO 019N 096W 22 SE1/4SE1/4 3.62 West Red 

P7764S 06/26/1974 Fully Adjudicated USDI BLM Middle Red Draw (Index #4346) Stock Reservoir STO 019N 096W 24 SW1/4NE1/4 3.62 MIDDLE RED 

P9763S 09/12/1985 -- -- Lower Middle Red Draw Stock Reservoir STO 019N 096W 24 SW1/4NE1/4 5.96 Middle Red 

CR08/317 06/26/1974 -- USDI BLM Middle Red Draw (Index #4346) Stock Reservoir STO 019N 096W 24 SW1/4NE1/4 3.62 MIDDLE RED P11369S 09/09/1991 -- -- Tiny Draw Stock Reservoir STO 019N 097W 26 NE1/4NE1/4 1.60 Tiny DraP7778S 06/26/1974 Fully Adjudicated USDI BLM Upper Red Draw (Index #4351) Stock Reservoir STO 019N 097W 36 SW1/4NE1/4 3.62 Red Wash 

CR08/076 06/26/1974 -- USDI BLM Upper Red Draw (Index #4351) Stock Reservoir STO 019N 097W 36 SW1/4NE1/4 3.62 Red Wash 

UW05/142 04/01/1983 --

COLORADO 

INTERSTATE GAS 

COMPANY 

Table Rock No. 1 Well,, Enl. MIS 019N 098W 23 SW1/4NE1/4 0.00 -- 

UW05/143 04/01/1983 --

COLORADO 

INTERSTATE GAS 

COMPANY 

Table Rock No. 2 Well,, Enl. MIS 019N 098W 23 NW1/4SE1/4 0.00 -- 

UW05/144 04/01/1983 --

COLORADO 

INTERSTATE GAS 

COMPANY 

Table Rock No. 3 Well,, Enl. MIS 019N 098W 23 NE1/4SW1/4 0.00 -- 

UW05/145 04/01/1983 --

COLORADO 

INTERSTATE GAS 

COMPANY 

Table Rock No. 4 Well,, Enl. MIS 019N 098W 23 SW1/4NE1/4 0.00 -- 

UW05/146 04/01/1983 --

COLORADO 

INTERSTATE GAS 

COMPANY 

Table Rock No. 5 Well,, Enl. MIS 019N 098W 23 SW1/4NE1/4 0.00 -- 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P5143R 09/28/1939 Unadjudicated USDI, DIVISION OF GRAZING Willow Draw Reservoir STO 020N 091W 6 SE1/4SE1/4 12.48 Willow Dr

P5172R 09/28/1939 Unadjudicated USDI - Grazing Service Latham Reservoir STO 020N 092W 14 SE1/4SE1/4 5.51 Latham D

UW03/433 06/30/1977 -- UNION PACIFIC RAILROAD COMPANY CRESTON #1 MIS 020N 092W 15 SW1/4SW1/4 10.00 -- 

UW03/434 08/30/1977 -- UNION PACIFIC RAILROAD COMPANY ENL CRESTON #1 MIS 020N 092W 15 SW1/4SW1/4 10.00 -- 

P10712S 05/17/1989 -- -- Backbone Stock Reservoir STO 020N 092W 20 NE1/4NE1/4 1.70 LATHAM DP10286S 10/05/1987 -- -- 44 Ranch Stock Reservoir STO 020N 092W 22 NE1/4NE1/4 3.68 Ollie's Dr

P10282S 10/05/1987 -- -- 44 Ranch Pit No. 2 NP Stock Reservoir STO 020N 092W 30 SE1/4SW1/4 4.68 Kerry's C

P8707S 08/20/1980 Fully Adjudicated P. H. LIVESTOCK CO. Hansen Stock Reservoir STO 020N 093W 29 SE1/4SE1/4 1.00 Hansen D

CR09/495 08/20/1980 -- P. H. LIVESTOCK CO. Hansen Stock Reservoir STO 020N 093W 29 SE1/4SE1/4 1.00 Hansen D

P9203R 04/03/1979 Fully Adjudicated Town of Wamsutter Wamsutter Wastewater Treatment Reservoir IND 020N 094W 26 SE1/4SW1/4 73.45 Latham D

CR11/052 04/03/1979 -- TOWN OF WAMSUTTER Wamsutter Wastewater Treatment Reservoir IND 020N 094W 26 SW1/4SW1/4 0.00 Latham D

UW06/247 02/06/1978 -- DOUG AND DARLENE DOWLIN J W S 101 Well MIS 020N 094W 34 NE1/4SE1/4 100.00 -- 

UW09/293 11/30/1981 -- THE ESTATE OF DORIS M. BATH Norton No. 1 Well MIS 020N 094W 34 SW1/4SE1/4 150.0 -- 

P3510R 11/29/1918 -- Rasmusson Sheep Co. Basine Reservoir IRR; STO; COMBBU 020N 095W 16 NE1/4SW1/4 1,216.85 RED WASH 

P2265E 05/16/1910 -- Rasmusson Sheep Co. Rasmussen Ditch #1 {Enl. of} IRR 020N 095W 33 SW1/4SW1/4 -- NAMING ER

P10283S 10/05/1987 -- -- Tipton Road Well Pit. STO 020N 096W 6 NW1/4NW1/4 2.33 SCARLET SA

DRAW 

P10601S 01/04/1989 -- -- G. L. No. 1 Stock Reservoir STO 020N 097W 2 1.20 TWIN PEON 

P10676S 03/31/1989 -- -- North Creston No. 4 Stock Reservoir STO 021N 091W 28 SW1/4SW1/4 14.00 South Cresto

P15043D 03/26/1918 -- SAVAGE LIVESTOCK CO. Savage Supply Ditch RES; STO 021N 091W 28 NE1/4SE1/4 0.00 South CrestoP3472R 03/26/1918 -- SAVAGE LIVESTOCK CO. Savage Reservoir STO 021N 091W 28 SE1/4NE1/4 14.05 South Cresto

P10876S 01/24/1990 Unadjudicated -- Latham Stock Reservoir STO 021N 092W 2 NW1/4NW1/4 1.19 Separation 

P10530S 12/19/1988 -- -- Field Check Stock Reservoir STO 021N 092W 21 NW1/4NE1/4 0.50 Farmer D

P10505S 09/30/1988 Fully Adjudicated P H Livestock Co. Niels Stock Reservoir STO 021N 092W 25 NW1/4NW1/4 4.36 Barren D

CR12/355 09/30/1988 -- JOHN EDWARD PREECE (SELLER) Niels Stock Reservoir STO 021N 092W 25 NW1/4NW1/4 4.36 Barren DP10506S 09/30/1988 Unadjudicated P H Livestock Co. Creston Stock Reservoir STO 021N 092W 27 SE1/4NW1/4 5.67 Creston D

F-18 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

CR12/356 09/30/1988 -- JOHN EDWARD PREECE (SELLER) Creston Stock Reservoir STO 021N 092W 27 SE1/4NW1/4 5.67 Creston D

P19495D 12/21/1940 Unadjudicated K.H. HADSELL Diversion Ditch RES 021N 093W 27 NE1/4SE1/4 0.00 Five Mile D

P5386R 12/21/1940 Unadjudicated K.H. HADSELL Hadsell Reservoir IRR; STO; COMBBU 021N 093W 33 NE1/4NE1/4 363.17 Hadsell D

P10879S 01/24/1990 -- -- Five Mile Stock Reservoir STO 021N 095W 35 NW1/4SW1/4 1.07 Five Mile D

P13667R 05/24/2010 Complete ROBERT HARDEK HARDEK STO; WL 022N 091W 9 SE1/4SE1/4 -- Cameno D

P5751S 12/12/1966 Fully Adjudicated LOUIS LARSEN SHEEP CO. Pronghorn Stock Reservoir STO 022N 093W 5 NE1/4NW1/4 1.93 East Fork Sou

Gulch 

CR04/150 12/12/1966 -- LOUIS LARSEN SHEEP CO. Pronghorn Stock Reservoir STO 022N 093W 5 NE1/4NW1/4 1.93 East Fork Sou

Gulch 

P5071S 03/29/1965 Unadjudicated PIONEER LIVESTOCK CO. Monument Lake Stock Reservoir STO 022N 093W 31 SE1/4NW1/4 0.95 MONUMENT L 

P10528R 05/05/1997 Unadjudicated -- Wamsutter Saltwater Disposal No. 3 Reservoir IND; TEM; COMBBU 022N 094W 35 SW1/4NW1/4 7.50 Monument 

P13446R 05/07/2009 Incomplete --

ENLARGED WAMSUTTER 

EVAPORATION POND 2, 

CELLS 3 AND 4 

RESERVOIR 

IND 022N 094W 35 SW1/4NW1/4 -- Monument 

P7739S 06/24/1974 Unadjudicated Curtis Rochelle Stranburg Stock Reservoir STO 022N 095W 33 SW1/4NE1/4 1.54 STRANBURG 

P9423R 08/31/1984 Incomplete KENNECOTT URANIUM CO REB FINAL IMPOUNDMENT RESERVOIR WL 023N 094W 3 SW1/4NE1/4 3,128.0 Battle Spring 

P5174R 09/28/1939 Unadjudicated USDI - Grazing Service Sour Dough Reservoir STO 023N 094W 26 SW1/4SW1/4 24.99 SOUR DOUGH 

P25157D 08/11/1976 Unadjudicated -- Siberia Ridge Unit Well #5 (Water Haul) DRI; IND; OIL; TEM 023N 096W 25 NW1/4NW1/4 0.39 Lost Creek 

P547R 07/20/1904 Fully Adjudicated SWEETWATER CATTLE CO. Hay Reservoir IRR; STO; COMBBU 023N 097W 2 NW1/4SW1/4 2.480.0 Red Cre

P6146D 07/20/1904 Fully Adjudicated SWEETWATER CATTLE CO. Hay Ditch IRR; STO 023N 097W 2 NW1/4SW1/4 4.63 Red Cre

CC26/440 07/20/1904 -- JOHN W. HAY Hay Reservoir DOM; IRR; STO 023N 097W 2 NW1/4SW1/4 2,480.0 Red Cre

CC26/441 07/20/1904 -- JOHN W. HAY Hay Ditch DOM; IRR; STO 023N 097W 2 NW1/4SW1/4 0.00 Red Cre

CC46/411 07/20/1904 -- SWEETWATER CATTLE CO. Hay Ditch DOM; IRR; STO 023N 097W 2 NW1/4SW1/4 -- Red Cre

CR01/012 07/20/1904 -- SWEETWATER CATTLE CO. Hay Reservoir DOM; IRR; STO 023N 097W 2 NW1/4SW1/4 -- Red CreP12791S 03/22/1996 -- -- Sand Dune (6474) Stock Reservoir STO 023N 097W 13 SE1/4NE1/4 0.35 Red Desert 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-4. Surface water rights within 1 mile of the CD-C project area, continued WR Number 

Priority 

Date Status Company/Individual Facility Name Uses Twn Rng Sec QtrQtr Total Flow Source Name 

P3983R 03/07/1925 -- John Bugas Eagle Nest Reservoir 

DOM; IRR; 

STO; 

COMBBU 

024N 095W 3 NE1/4NE1/4 1,364.92 Lost Cre

P222S 06/13/1946 Complete BESSIE MCINTOSH EAGLE DRAW STOCK RESERVOIR STO 024N 095W 12 SE1/4SE1/4 1.24 Eagle DrCC38/117 07/09/1912 -- JOHN W. HAY Bush Creek Ditch RES 024N 096W 7 NW1/4NW1/4 0.00 -- 

CC38/119 08/11/1911 -- JOHN W. HAY Bush Lake Reservoir IRR; STO 024N 096W 7 NW1/4NW1/4 1,685.9 Bush Cre

CC38/114 10/17/1906 -- JOHN W. HAY Bush Lake Cut Ditch IRR; STO 024N 096W 18 SE1/4NW1/4 0.00 Bush Cre

CC46/410 10/17/1906 -- SWEETWATER CATTLE CO. Bush Lake Cut Ditch DOM; IRR; STO 024N 096W 18 SE1/4NW1/4 -- Bush Cre

P12784S 03/22/1996 -- -- Lost Creek Rim (6475) Stock Reservoir STO 024N 096W 24 SW1/4SW1/4 0.48 NORTH LO

DRAW 

P11131S 09/06/1990 -- -- Karo Stock Reservoir STO 024N 096W 35 SE1/4SE1/4 0.70 LOST DR

P12790S 03/22/1996 -- -- Bush Lake Water (6257) Stock Reservoir STO 024N 097W 12 NE1/4NE1/4 0.53 DRAINAGE O

LAKE 

P11341D 07/09/1912 Fully Adjudicated SWEETWATER CATTLE COMPANY Bush Creek Ditch IRR; RES 024N 097W 12 NW1/4NW1/4 0.00 -- 

P6453D 01/19/1905 Fully Adjudicated John W. Hay Hay Supply Ditch IRR; RES; STO 024N 097W 14 NW1/4NE1/4 0.00 Bush Cre

CC38/113 01/19/1905 -- JOHN W. HAY Hay Supply Ditch RES 024N 097W 14 NW1/4NE1/4 0.00 Bush Cre

P12796S 03/22/1996 -- -- Presidio (6256) Stock Reservoir STO 024N 097W 26 NE1/4SW1/4 0.42 Luman Butte P11339D 08/28/1911 Fully Adjudicated SWEETWATER CATTLE COMPANY Hay Ditch No. 1 IRR; STO 024N 097W 35 NE1/4SE1/4 34.43 Red Cre

P11340D 07/09/1912 -- SWEETWATER CATTLE COMPANY Hay Ditch No. 2 IRR; STO 024N 097W 35 NE1/4SE1/4 8.76 Red Cre

CC38/115 07/09/1912 -- JOHN W. HAY Hay Ditch No. 2 IRR; STO 024N 097W 35 NE1/4SE1/4 8.70 Red Cre

CC38/116 08/28/1911 -- JOHN W. HAY Hay Ditch No. 1 IRR; STO 024N 097W 35 NE1/4SE1/4 32.12 Red Cre

P2339R 08/11/1911 Fully Adjudicated SWEETWATER CATTLE CO. Hay Reservoir, Enlarged IRR; STO; COMBBU 024N 097W 35 SE1/4NE1/4 5,846.59 Red Cre

CC38/118 08/11/1911 -- JOHN W. HAY Hay Reservoir, Enl. IRR; STO 024N 097W 35 SE1/4NE1/4 5,846.59 Red Cre

Notes for non-mining-related surface water rights within 1 mile of the CD-C project area: Search Conducted February 15, 2011 Water rights were searched to the nearest quarter-quarter of each section listed above. Any part of a quarter-quarter section that lies within one mile of th

included. A double dash (--) indicates no information is available. Record suffixes are denoted as follows: "A" Adjudicated (finalized) rights; unless the right is a territorial appropriation, there will be a match in the reference column from one of the followin

unadjudicated portion 

F-20 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

"D" "E" "R""S" 

Ditch or pipeline permit 

Enlargement of a ditch or pipeline permit 

 Reservoir permit 

Stock reservoir permit 

Use Codes COMBBU OMFIS FLO FTH

Combined Beneficial Use 

 Domestic 

Fish Propagation 

Flood Control 

 Flow-through Non-consumptive 

INDIRRMIS OILREC Industrial 

Irrigation 

Miscellaneous 

 Oil Refining/Production 

Recreation 

RES STO TEM WET WL 

Reservoir supply 

Stock 

Temporary 

Wetlands Wildlife 

Separate water rights with a status code of ABA, A&C, AME, CAN, ELI, EXP, REJ, or TRA were eliminated from the search area listing provided above (i

the mining companies), as none of these use codes represent a valid current right. Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-5. WDEQ use classifications1 Class of Water Outstanding Values Drinking Water Game Fish

Non-Game FishFish ConsumptionOther Aquatic LifeRecreationWildlifeAgricultureIndustryScenic Value 

2AB No Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes 

2C No No Yes Yes Yes Yes Yes Yes Yes Yes Yes 

3A No No No No Yes Yes Yes Yes Yes Yes Yes 

3B No No No No No Yes Yes Yes Yes Yes Yes 

4B No No No No No Yes Yes Yes Yes Yes Yes 

4C No No No No No No Yes Yes Yes Yes Yes 

1 Only those classifications used in the CD-C project area are included in this list. 

2 "Yes" means that it is protected for the use specified, and "No" means that it is not. 

Source: WDEQ 2001 

F-22 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-6. WDEQ use-classified water bodies near and in the CD-C project area

 Reservoirs, Lakes, and Ponds (Use Classification) Source Water Acres Surface 

Ownership 

Alkali Lake (3A) Spring Fed 24 BLM/WGFD 

Bush Lake (3B) Bear Creek 334 BLM 

Chain Lakes (3A) Spring Fed 1,000 BLM/WGFD 

Circle Bar Lake (3A) Spring Fed 240 WGFD 

Eightmile Lake (3A) Spring Fed 75 BLM/PRIVATE 

Hansen Lake (3B) Spring Fed 52 WGFD 

Hay Reservoir (3B) Red Creek 1,000 BLM/STATE 

Lost Creek Lake (3B) Lost Creek 824 BLM/STATE 

Mud Lake (3A) Spring Fed 98 BLM 

Robber’s Gulch Reservoir (2AB) Robber’s Gulch 50 BLM 

Streams and Springs Classification 

Upper Green/White-Yampa 

Little Snake River1 2AB 

Muddy Creek (mouth to Section 29, T17N, R89W) 1,2 2C 

Barrel Springs Draw2 3B 

Windmill Draw2 3B 

North Barrel Springs Draw2 3B 

North Prong Red Wash2 3B 

Robber’s Gulch1,2 3B 

Bitter Creek1,2 2C 

Great Divide Basin

 Dugout Draw1,2 3B 

Fivemile Ditch2 3B 

Echo Springs2 3B 

 Separation Creek1 4C

 Fillmore Creek2 3B 

 Creston Draw1,2 3B 

Buck Draw1,2 3B 

Mud Springs2 3B 

Lost Creek1,2 3B 

Red Creek1,2 4B 

Bear Creek1,2 3B 

1

 Located near CD-C project area.
 

2

 Located within CD-C project area. 

Sources for reservoirs, lakes, and ponds: WDEQ 2001, and WGFD 2007b
 

Sources for streams and springs: WDEQ 2010 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-23 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-7. Surface water quality at selected sites within and adjacent to the CD-C project area Station Number 

S U R F A C E W A T E R Q U A L I T Y S T A T I O N 

USGS 

Little Snake River Muddy Creek Lower Barrel Springs Draw Bitter Creek Upper Filmore Creek 

09257000 09259050 09258900 09259000 09258980 09216310 09216545 09219240 

Monitirong site located in CD-C project area? No No No No No Yes No Yes 

Sample period 1957–1988 1980–1997 1976–1978 1957–1991 

April 

2006– 

present1 

1978–1979 1975– 1981 4/18/1979 

Number of samples2 107 100 3 41 64 7 155 1 

pH 8.1 8.1 8.6 8.2 8.3 8.4 8.4 7.7 

Conductance, μmhos/cm (mean) 259(34) 366(90) 1,350(2) 966(35) 1,812(64) 533(4) 1,755(149) 700(1) 

Conductance, μmhos/cm (min) 82 87 600 529 448 340 280 700 

Conductance, μmhos/cm (max) 460 855 2,100 1,790 3,990 1,000 4,500 700 

TDS (mean) 158(9) 243(17) 913(2) 346(1) 1,249(55) 619(1) 1,289(78) 495(1) 

TDS(min) 46 87 396 346 267 619 295 495 

TDS (max) 260 540 1,430 346 2,810 619 2,740 495 

Suspended solids3 (mean) 154(101) 228(25) 6,198(2) 3,191(41) 300(55) nm 1,843(105) 141(1) Suspended solids3 (min) 4 6 195 7 13 nm 22 141 Suspended solids3 (max) 1,180 852 12,200 22,500 2,530 nm 21,900 141 

Turbidity, NTU 13 167 1,260 nm 55 17 305 984 

Calcium 30 34 54 42 79 28 40 32 Magnesium 8 12 44 40 50 2 27 68 

Potassium 2 2 7 9 4 5 3 7 

Sodium 11 26 200 286 274 205 348 22 Bicarbonate 159 190 373 308 nm 500 369 68 

Sulfate 25 54 380 320 515 100 590 320 

Chloride 3 2 65 32 126 12 39 12 Iron, μmhos/cm g/L 74 164 105 nm 30 nm 103 210 

Hardness (CaCO3) 111 151 315 270 404 80 211 nm 

Dissolved oxygen 9 10 11 10 10 5.2 9.7 5 

1 Daily mean values analyzed April 18, 2006 to February 2, 2011.2 Total number of grab samples analyzed; not every parameter was analyzed in every sample. 3 Total concentration; except as noted here, all reported values represent dissolved concentrations. 

JTU - Jackson turbidity units.nm - Not measured. 

 (34) - Number of samples analyzed for this parameter.

All units are mg/L except as noted. Source: WRDS 2007, USGS 2011

F-24 Continental Divide-Creston Natural Gas Development Project D
 

 

 

 

 

 

 

 

 

APPENDIX F—SUPPORTING WATER RESOURCES DATA 

Table F-8. Muddy Creek water quality1 

Parameter Unit Count Mean2 Maximum Minimum 

Specific Conductance μmhos 98 1,416.9 3,990.0 0.3 

Total dissolved solids mg/L 59 1,236.0 2,810.0 267 

Total suspended solids mg/L 59 2,595.2 22,500.0 7.0 

Turbidity NTU 22 240.8 2,500.0 10.0

 pH standard units 88 8.4 9.5 7.6

 Dissolved oxygen mg/L 78 9.7 17.6 6.1

 Hardness as CaCO3 mg/L 75 371.7 744.0 54.6

 Alkalinity as CaCO3 mg/L 55 311.0 478.0 117.0

 Calcium mg/L 20 68.8 130.0 22.0

 Magnesium mg/L 74 43.8 97.1 3.9

 Sodium mg/L 75 222.0 693.0 3.6

 Potassium mg/L 76 4.5 9.8 1.3

 Sodium adsorption ratio none 60 5.6 11.4 0.1

 Sulfate mg/L 75 437.8 1,210.0 21.0

 Chloride mg/L 75 95.7 417.0 0.7

 Bicarbonate mg/L 20 227.1 565.0 121.0

 Carbonate mg/L 14 11.2 114.0 0.0

 Fluoride mg/L 65 0.9 11.0 0.2

 Silica mg/L 60 12.6 39.0 3.7

 Coliforms, fecal count/100 mL 8 131.3 420.0 20.0

 Aluminum, dissolved μg/L 1 < 100.0 < 100.0 < 100.0

 Arsenic, dissolved μg/L 57 2.0 3.2 0.8

 Barium, dissolved μg/L 2 76.5 < 100.0 53.0

 Beryllium, dissolved μg/L 1 < 0.01 < 0.01 < 0.01 

 Boron, dissolved μg/L 3 153.3 360.0 20.0

 Cadmium, dissolved μg/L 2 0.02 0.04 0.0

 Chromium, dissolved μg/L 1 0.5 < 1.0 < 1.0 

 Copper, dissolved μg/L 2 2.1 2.2 < 2.0 

 Iron, dissolved μg/L 10 253.6 876.0 20.0

 Lead, dissolved μg/L 1 0.1 0.1 0.1

 Manganese, dissolved μg/L 5 65.8 218.0 < 10 

 Mercury, dissolved μg/L 1 < 0.5 < 0.5 < 0.5 

Molybdenum, dissolved μg/L 1 8.0 8.0 8.0

 Selenium, dissolved μg/L 3 4.3 8.0 2.0

 Silver, dissolved μg/L 2 0.0 0.0 0.0

 Uranium, dissolved μg/L 3 10.1 16.0 6.9

 Zinc, dissolved μg/L 2 12.9 < 20 5.7

 Radium 226 pCi/L 2 0.5 1.2 0.17

 Gross alpha pCi/L 2 22.5 23.0 22.0

 Gross beta pCi/L 2 6.8 7.0 < 6.5 

1 Based on Sampling Sites 9217220, 09258900, 09258980, 09259000, MCR3, MCDAD, 412325107244101, 412614107452101 

2

 Geometric mean 

μmhos = micromhos 

mg/L = milligrams per liter 

μg/L = micrograms per liter 

pCi/L = picocuries per liter 

Source: WRDS 2007 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-25 
 

APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-9. 2010 303(d) water bodies in the CD-C project area with impairments or threats 

Surface Water Impairments or 

Threats Location Impairments/ Threats 

Use Impaired/ 

Threatened Date Priority 

Little Snake River Basin (HUC 14050003 and HUC 14050004) 

Muddy Creek Threats West of State Hwy 

789 

Habitat 

degradation 

Non-game fish; 

aquatic life 1996 Moderate 

Muddy Creek Threats 

Above Alamosa 

Gulch to Littlefield 

Creek 

Habitat 

degradation 

Cold fish, 

aquatic life 1996 Moderate 

Muddy Creek Threats 

Below Youngs 

Draw upstream to 

Deep Creek 

Chloride, 

Selenium Aquatic Life 2010 

Not 

Identified 

In Report

 Source: WDEQ 2010 

F-26 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-10. Water-bearing characteristics of geologic formations in the Washakie and Great Divide 

structural basins 

Era Period Geologic Unit Thickness 

HYDROLOGIC PROPERTIES 

Well 

Yield 

(gpm) 

Transmissivity 

(gpd/ft) 

Permeability 

(gpd/ft2

) 

Cenozoic Quaternary 0–70 <30 168-560 21-62 

Tertiary Washakie 

Formation (Uinta & 

Bridger Formations) 

0–3,200 

Laney Member of 

Green River Fm. 

0–1,500 <200 100 - 300 10 

Wasatch Fm. 0–4,000+ 30–50 150–10,000 0.04–18.2 

Battle Springs Fm. 0–4,700 1–157 29–3,157 NM 

Fort Union Fm. 0–2,700+ 3-300 <2,500 <1 

Mesozoic 

Upper 

Cretaceous 

Lance Fm. 0–4,500+ <25 <20 0.007–8.2 

Fox Hills Sandstone 0–400 NM 10-20 0.9 

Lewis Shale 0–2,700+ 2–252 0.03–50 0.002–0.9 

Mesaverde Group 

(excl. Almond Fm.) 

0–2,800 <100 <3,000 NM 

Baxter Shale (incl. 

Steele Shale and 

Niobrara Fm.) 

2,000– 

5,000+ 

Major regional aquitard between Mesaverde 

and Frontier aquifers. Hydrologic data 

unavailable. 

Frontier Fm. 190–900+ 1–100+ <100–6,500 NM 

Lower 

Cretaceous 

Mowry Shale 150–525 Regional aquitard. Hydrologic data 

unavailable. 

Thermopolis Shale 

(incl. Muddy 

sandstone) 

40–235 

(20–155) 

Considered a leaking confining unit. Hydrologic 

data unavailable. 

Cloverly Fm. 45–240 25–120 340–1,700 1–177 

Upper Jurassic Morrison Fm. 170–450+ Confining unit between Cloverly and 

Sundance-Nugget aquifers. Hydrologic data 

unavailable. 

Sundance Fm. 130–450+ 27–35 12–3,500 NM 

Lower JurassicUpper Triassic Nugget Sandstone 0–650+ 35–200 <2,166 NM 

Triassic Chugwater Fm. 900– 

1,500+ 

Confining unit between Sundance-Nugget and 

Paleozoic aquifers. Hydrologic data 

unavailable. 

MesozoicPaleozoic Lower Triassic 

Permian 

Phosphoria 

Fm.(incl. Goose 

Egg Fm.) 

170–460 Probable poor water-bearing capabilities due 

tallow permeability. Hydrologic data 

unavailable. 

Paleozoic PermianPennsylvanian Tensleep Fm. 0–840+ 24–400 1–374 NM 

Middle and 

Lower 

Pennsylvanian 

Amsden Fm. 2–260+ Probable poor water-bearing capabilities due 

to predominance of fine-grained sediments. 

Mississippian Madison Limestone 5–325+ <400 Variable NM 

Paleozoic Cambrian Indef. rocks 0–800+ 4–250 NM NM 

Precambrian N/A Igneous and 

metamorphic rocks 

Unknown 10–20 1<1,000 Generally high 

in upper 200 ft 

of unit 

Adapted from Table V-1 in Collentine et al. (1981). Formations not encountered in CD-C project area have been omitted. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-27 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-11. Existing groundwater rights within 1 mile of the CD-C project area, February 2011 

SEO Use Designation (As Assigned) Groundwater Rights 

Monitoring 366 

Stock 249 

Miscellaneous 198 

Coalbed Methane (Coalbed methane natural gas) 153 

Domestic 35 

Domestic; Stock 34 

Industrial 12 

Miscellaneous; Monitoring 6 

Municipal 6 

Domestic; Miscellaneous 4 

Miscellaneous; Stock 4 

Domestic; Irrigation; Stock 3 

Industrial; Miscellaneous 3 

Domestic; Miscellaneous; Stock 2 

Industrial; Stock 2 

Blank 1 

Domestic; Industrial; Irrigation; Miscellaneous 1 

Domestic; Irrigation 1 

Test well 1 

Total 1,081 

Use Included in SEO Designation Groundwater Rights 

Monitoring 372 

Stock 294 

Miscellaneous 218 

Coalbed Methane (Coalbed methane natural gas) 153 

Domestic 80 

Industrial 18 

Municipal 6 

Irrigation 5 

Test Well 1 

Total1 1,147 

1

 Total (1,147) exceeds the number of permitted groundwater rights (1,081) since individual rights 

may have multiple uses 

Source: SEO 2011 

F-28 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow ToP160584W 07/19/2004 -- MIS 014N 091W 18 NW1/4NW1/4 10 

P134628W 05/02/2001 Complete Matthew L. or Sherry L. Weber STK 014N 091W 19 NW1/4SE1/4 0 

P152301W 01/09/2003 Complete Devon Energy Production Co., LP MIS 014N 091W 19 NW1/4SE1/4 15 

P191830W 01/07/2003 Incomplete MATT WEBER MIS 014N 091W 19 NW1/4SE1/4 0 

P106883W 08/06/1997 Complete LEE/DONNA JONS STK 014N 091W 30 NW1/4NE1/4 5 

P6415P 11/09/1967 Complete LEELAND U. GRIEVE STK 014N 091W 32 SE1/4SE1/4 10 P92382W 07/16/1993 -- -- MIS 014N 092W 10 SE1/4NE1/4 120 

P152940W 08/04/2003 Complete Devon Energy Production Co., LP MIS 014N 092W 12 NE1/4NE1/4 30 1

P17372P 12/12/1961 Complete -- STK 014N 092W 12 SW1/4NE1/4 5 

P178794W 12/11/2006 -- Devon Energy Production Co. MIS 014N 092W 23 NE1/4SE1/4 40 

P69993W 05/10/1985 Complete -- MON 015N 092W 3 NE1/4NW1/4 0 

P69994W 05/10/1985 Complete -- MON 015N 092W 3 SE1/4NW1/4 0 

P69996W 05/10/1985 Complete -- MON 015N 092W 3 SW1/4NW1/4 0 

P69997W 05/10/1985 Complete -- MON 015N 092W 3 SW1/4NW1/4 0 

P69998W 05/10/1985 Complete -- MON 015N 092W 3 SW1/4NW1/4 0 

P69999W 05/10/1985 Complete -- MON 015N 092W 3 NW1/4SW1/4 0 P70000W 05/10/1985 Complete -- MON 015N 092W 3 NW1/4SW1/4 0 P70002W 05/10/1985 Complete -- MON 015N 092W 3 SW1/4NW1/4 0 

P70003W 05/10/1985 Complete -- MON 015N 092W 4 NE1/4SE1/4 0 

P70005W 05/10/1985 Complete -- MON 015N 092W 4 SE1/4SE1/4 0 

P70018W 05/10/1985 Complete -- MON 015N 092W 4 SE1/4NE1/4 0 

P70019W 05/10/1985 Complete -- MON 015N 092W 4 SE1/4NE1/4 0 

P70020W 05/10/1985 Complete -- MON 015N 092W 4 SW1/4NE1/4 0 

P70022W 05/10/1985 Complete -- MON 015N 092W 4 NW1/4NE1/4 0 

P70023W 05/10/1985 Complete -- MON 015N 092W 4 NW1/4NE1/4 0 

P70024W 05/10/1985 Complete -- MON 015N 092W 4 NW1/4NE1/4 0 

P70016W 05/10/1985 Complete -- MON 015N 092W 5 NE1/4NE1/4 0 

P70017W 05/10/1985 Complete -- MON 015N 092W 5 NE1/4NE1/4 0 

P70021W 05/10/1985 Complete -- MON 015N 092W 5 SW1/4NE1/4 0 

P103904W 09/24/1996 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 

P103905W 09/24/1996 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 

P103906W 09/24/1996 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 

P104655W 12/06/1996 Incomplete -- MIS 015N 092W 17 SE1/4NW1/4 5 

P112143W 09/30/1998 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 

P138675W 08/31/2001 Complete -- MIS 015N 092W 17 SE1/4NW1/4 1.5 

P145959W 07/15/2002 -- Devon Energy Production Co., LP MIS 015N 092W 17 SE1/4NW1/4 0.2 

P70693W 07/05/1985 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 

P70694W 07/05/1985 Complete -- MON 015N 092W 17 SW1/4NW1/4 0 

P70695W 07/05/1985 Complete -- MON 015N 092W 17 NE1/4NW1/4 0 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P70696W 07/05/1985 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 P70697W 07/05/1985 Complete -- MON 015N 092W 17 SE1/4NW1/4 0 P70698W 07/05/1985 Complete -- MON 015N 092W 17 SE1/4SW1/4 0 

P113242W 12/03/1998 -- SHEEHAN RANCHES STK 015N 093W 3 NW1/4NE1/4 0 

P179158W 01/17/2007 -- Patrick & Judith Sheehan MIS; STK 015N 093W 3 NW1/4NE1/4 50 

P17358W 12/20/1972 Complete -- STK 015N 093W 6 SW1/4SW1/4 5 P170496W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 NE1/4NW1/4 58 

P170497W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 NE1/4NE1/4 58 

P170498W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 SW1/4NE1/4 58 

P170499W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 SE1/4SE1/4 58 

P170500W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 SW1/4NW1/4 58 

P170501W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 SE1/4NW1/4 58 P170502W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 NW1/4SW1/4 58 

P170503W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 SE1/4SW1/4 58 

P170504W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 NW1/4SE1/4 58 P170505W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 2 SE1/4SE1/4 58 

P170506W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 NE1/4NW1/4 58 

P170507W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 NE1/4NE1/4 58 

P170508W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 SW1/4NE1/4 58 

P170509W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 SE1/4NE1/4 58 P170510W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 SW1/4NW1/4 58 

P170511W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 SE1/4NW1/4 58 P170512W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 NW1/4SW1/4 58 

P170513W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 SE1/4SW1/4 58 

P170514W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 NW1/4SE1/4 58 P170515W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 3 SE1/4SE1/4 58 

P170545W 08/18/2005 -- Steve F. Adams MIS 016N 092W 5 NE1/4SE1/4 10 

P186105W 03/06/2008 Unadjudicated NABORS DRILLING USA, LP MIS 016N 092W 5 NE1/4SE1/4 60 

P74765W 06/09/1987 Complete -- MON 016N 092W 5 SW1/4SE1/4 0 

P6658P 12/31/1916 Complete GEORGE W. DEW DOM; STK 016N 092W 7 SE1/4NE1/4 10 P74767W 06/09/1987 Complete -- MON 016N 092W 8 SE1/4SE1/4 0 

P170844W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 NW1/4NE1/4 58 

P170845W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 SE1/4NE1/4 58 

P170846W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 NW1/4NW1/4 58 

P170847W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 SE1/4NW1/4 58 P170848W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 NW1/4SE1/4 58 

P170849W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 SE1/4SE1/4 58 

P170850W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 NW1/4SW1/4 58 

P170851W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 10 SE1/4SW1/4 58 P170384W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 SE1/4SE1/4 58 

F-30 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P170852W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 NW1/4NE1/4 58 

P170853W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 SE1/4NE1/4 58 

P170854W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 NW1/4NW1/4 58 

P170855W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 SE1/4NW1/4 58 

P170856W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 NW1/4SE1/4 58 

P170857W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 NW1/4SW1/4 58 

P170858W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 11 SE1/4SW1/4 58 

P255W 10/15/1959 Complete FRANK WILLIAMS STK 016N 092W 17 NW1/4SE1/4 11.5 

P74768W 06/09/1987 Complete -- MON 016N 092W 20 NE1/4SE1/4 0 

P170898W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 NW1/4NE1/4 58 

P170899W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 SE1/4NE1/4 58 

P170900W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 NW1/4NW1/4 58 

P170901W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 SE1/4NW1/4 58 P170902W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 NW1/4SE1/4 58 

P170903W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 SE1/4SE1/4 58 

P170904W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 NW1/4SW1/4 58 

P170905W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 21 SE1/4SW1/4 58 P170906W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 NW1/4NE1/4 58 

P170907W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 SE1/4NE1/4 58 

P170908W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 NW1/4NW1/4 58 

P170909W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 SE1/4NW1/4 58 

P170910W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 NW1/4SE1/4 58 

P170911W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 SE1/4SE1/4 58 

P170912W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 NW1/4SW1/4 58 

P170913W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 22 SE1/4SW1/4 58 

P170450W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 SE1/4NE1/4 58 

P170451W 09/02/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 SE1/4SE1/4 58 

P170914W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 NW1/4NE1/4 58 

P170915W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 NW1/4NW1/4 58 

P170916W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 SE1/4NW1/4 58 P170917W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 NW1/4SE1/4 58 

P170918W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 NW1/4SW1/4 58 

P170919W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 23 SE1/4SW1/4 58 

P170920W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 NW1/4NE1/4 58 

P170921W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 SE1/4NE1/4 58 

P170922W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 NW1/4NW1/4 58 

P170923W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 SE1/4NW1/4 58 P170924W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 NW1/4SE1/4 58 

P170925W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 SE1/4SE1/4 58 

P170926W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 NW1/4SW1/4 58 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P170927W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 27 SE1/4SW1/4 58 

P170928W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 28 NW1/4NE1/4 58 

P170929W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 28 SE1/4NE1/4 58 

P170930W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 28 SE1/4NW1/4 58 

P170931W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 28 NW1/4SE1/4 58 

P170932W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 28 SE1/4SE1/4 58 

P170933W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 28 SE1/4SW1/4 58 

P70061W 05/10/1985 Complete -- MON 016N 092W 28 SW1/4SW1/4 0 P78958W 01/17/1989 Complete -- MON 016N 092W 28 SE1/4SW1/4 0 

P70063W 05/10/1985 Complete -- MON 016N 092W 29 SE1/4SE1/4 0 

P70066W 05/10/1985 Complete -- MON 016N 092W 29 SE1/4SE1/4 0 

P70067W 05/10/1985 Complete -- MON 016N 092W 29 SE1/4SE1/4 0 

P70068W 05/10/1985 Complete -- MON 016N 092W 29 SE1/4SE1/4 0 

P70069W 05/10/1985 Complete -- MON 016N 092W 29 SE1/4SE1/4 0 

P70070W 05/10/1985 Complete -- MON 016N 092W 29 NW1/4SE1/4 0 

P70072W 05/10/1985 Complete -- MON 016N 092W 29 NE1/4SW1/4 0 

P70078W 05/10/1985 Complete -- MON 016N 092W 29 SE1/4SE1/4 0 

P17359W 12/20/1972 Complete -- STK 016N 092W 31 NE1/4SW1/4 5 

P70077W 05/10/1985 Complete -- MON 016N 092W 32 NE1/4NE1/4 0 

P78959W 01/17/1989 Complete -- MON 016N 092W 32 SE1/4NE1/4 0 

P70006W 05/10/1985 Complete -- MON 016N 092W 33 SW1/4NE1/4 0 

P70007W 05/10/1985 Complete -- MON 016N 092W 33 NE1/4SW1/4 0 

P70008W 05/10/1985 Complete -- MON 016N 092W 33 NE1/4SW1/4 0 

P70009W 05/10/1985 Complete -- MON 016N 092W 33 NW1/4SW1/4 0 P70010W 05/10/1985 Complete -- MON 016N 092W 33 NW1/4SW1/4 0 P70011W 05/10/1985 Complete -- MON 016N 092W 33 NW1/4SW1/4 0 P70012W 05/10/1985 Complete -- MON 016N 092W 33 SW1/4NW1/4 0 P70014W 05/10/1985 Complete -- MON 016N 092W 33 SW1/4SW1/4 0 

P70015W 05/10/1985 Complete -- MON 016N 092W 33 SW1/4SW1/4 0 

P78960W 01/17/1989 Complete -- MON 016N 092W 33 SW1/4NW1/4 0 

P78961W 01/17/1989 Complete -- MON 016N 092W 33 NW1/4NW1/4 0 

P78962W 01/17/1989 Complete -- MON 016N 092W 33 NW1/4NW1/4 0 

P78963W 01/17/1989 Complete -- MON 016N 092W 33 SW1/4SW1/4 0 

P78964W 01/17/1989 Complete -- MON 016N 092W 33 SW1/4SW1/4 0 

P170934W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 NW1/4NE1/4 58 

P170935W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 SE1/4NE1/4 58 

P170936W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 NW1/4NW1/4 58 

P170937W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 SE1/4NW1/4 58 

P170938W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 NW1/4SE1/4 58 

P170939W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 SE1/4SE1/4 58 

F-32 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P170940W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 NW1/4SW1/4 58 

P170941W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 34 SE1/4SW1/4 58 

P170942W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 NW1/4NE1/4 58 

P170943W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 SE1/4NE1/4 58 

P170944W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 NW1/4NW1/4 58 

P170945W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 SE1/4NW1/4 58 

P170946W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 NW1/4SE1/4 58 

P170947W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 SE1/4SE1/4 58 

P170948W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 NW1/4SW1/4 58 

P170949W 10/14/2005 -- Double Eagle Petroleum Company CBM 016N 092W 35 SE1/4SW1/4 58 

P95447W 05/24/1994 -- BP America Production Co. MIS 016N 093W 7 SE1/4NW1/4 -- 

P149036W 01/29/2003 Complete BP America Production Co. MIS 016N 093W 8 NW1/4SE1/4 84 

P190145W 07/14/2008 Complete BP America Production Co. MIS 016N 093W 13 NW1/4NW1/4 120 1,P149037W 01/29/2003 Complete BP America Production Co. MIS 016N 093W 14 SW1/4SE1/4 120 9,

P17365P 01/31/1966 Complete BP America Production Co. STK 016N 093W 14 NW1/4NW1/4 5 P75633W 10/01/1987 Incomplete BP America Production Co. MIS 016N 093W 32 SE1/4NW1/4 50 P120114W 11/03/1999 -- BP America Production Co. MIS 016N 094W 1 NW1/4SW1/4 150 

P183692W 11/05/2007 -- BP America Production Co. MIS 016N 094W 4 NE1/4NE1/4 175 

P191487W 09/25/2009 Incomplete BP America Production Co. STK 016N 094W 9 SW1/4SE1/4 

P17366P 10/26/1967 Complete BP America Production Co. STK 016N 094W 12 NE1/4NE1/4 5 

P191485W 09/25/2009 Incomplete BP America Production Co. STK 016N 094W 20 NE1/4NW1/4 25 

P17367P 10/26/1967 Complete BP America Production Co. STK 016N 094W 24 SE1/4SE1/4 5 

P157271W 03/25/2004 Incomplete BP America Production Co. MIS 016N 095W 1 NW1/4NW1/4 200 

P189204W 10/21/2008 Incomplete BP America Production Co. MIS 016N 095W 1 NW1/4NW1/4 200 

P154096W 09/17/2003 Complete BP America Production Co. STK 016N 095W 11 SE1/4NW1/4 6 

P189601W 11/26/2008 Fully Adjudicated BP America Production Co. MIS 017N 092W 3 NW1/4SE1/4 50 

P139582W 07/11/2001 -- BP America Production Co. MIS 017N 092W 5 NW1/4SE1/4 50 

P189600W 11/26/2008 Complete BP America Production Co. MIS 017N 092W 5 NW1/4SE1/4 50 

P17360W 12/20/1972 Complete BP America Production Co. STK 017N 092W 8 SE1/4NW1/4 5 

P27847W 09/17/1974 Complete BP America Production Co. DOM; STK 017N 092W 14 NW1/4NW1/4 3 

P70047W 05/10/1985 Complete BP America Production Co. MON 017N 092W 14 SW1/4SW1/4 0 

P169453W 07/13/2005 Complete BP America Production Co. DOM; MIS; STK 017N 092W 15 SW1/4SW1/4 20 

P173454W 02/28/2006 -- BP America Production Co. MIS 017N 092W 15 SE1/4SW1/4 25 2,

P56791W 05/05/1981 Complete BP America Production Co. STK 017N 092W 15 SE1/4SW1/4 25 2,

P70035W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 SE1/4SW1/4 0 

P70040W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 SW1/4SW1/4 0 

P70041W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 SE1/4SW1/4 0 

P70042W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 SE1/4SW1/4 0 

P70043W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 SE1/4SW1/4 0 

P70044W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SW1/4 0 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P70045W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NW1/4SE1/4 0 

P70046W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NW1/4SE1/4 0 

P70048W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70049W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SW1/4 0 

P70050W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NW1/4SE1/4 0 

P70051W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70052W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70053W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70054W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70055W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70056W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NE1/4SE1/4 0 

P70057W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 SW1/4NE1/4 0 

P70059W 05/10/1985 Complete BP America Production Co. MON 017N 092W 15 NW1/4NE1/4 0 

P70037W 05/10/1985 Complete BP America Production Co. MON 017N 092W 16 SE1/4SE1/4 0 

P70038W 05/10/1985 Complete BP America Production Co. MON 017N 092W 16 SE1/4SE1/4 0 

P70027W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 SE1/4NW1/4 0 

P70028W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 P70031W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 P70032W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 P70033W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 

P70034W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 

P70036W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 

P70039W 05/10/1985 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 

P78955W 01/17/1989 Complete BP America Production Co. MON 017N 092W 22 NW1/4NW1/4 0 

P170875W 10/14/2005 -- BP America Production Co. CBM 017N 092W 24 NW1/4SE1/4 58 

P170876W 10/14/2005 -- BP America Production Co. CBM 017N 092W 24 SE1/4SE1/4 58 

P170877W 10/14/2005 -- BP America Production Co. CBM 017N 092W 24 NW1/4SW1/4 58 

P170878W 10/14/2005 -- BP America Production Co. CBM 017N 092W 24 SE1/4SW1/4 58 

P170879W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 NW1/4NE1/4 58 

P170881W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 NW1/4NW1/4 58 

P170882W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 SE1/4NW1/4 58 

P170883W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 NW1/4SE1/4 58 

P170884W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 SE1/4SE1/4 58 

P170885W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 NW1/4SW1/4 58 

P170886W 10/14/2005 -- BP America Production Co. CBM 017N 092W 25 SE1/4SW1/4 58 

P170516W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 NW1/4NE1/4 58 

P170517W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 NW1/4NW1/4 58 

P170518W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 SE1/4NW1/4 58 

P170519W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 NW1/4SW1/4 58 

P170520W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 SE1/4SW1/4 58 

F-34 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P170521W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 NW1/4SE1/4 58 

P170540W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 SE1/4NE1/4 58 

P170541W 09/02/2005 -- BP America Production Co. CBM 017N 092W 26 SE1/4SE1/4 58 

P97449W 10/12/1994 -- BP America Production Co. STK 017N 092W 26 NE1/4SE1/4 0 

P74763W 06/09/1987 Complete BP America Production Co. MON 017N 092W 28 SE1/4SW1/4 0 

P78956W 01/17/1989 Complete BP America Production Co. MON 017N 092W 28 SE1/4SW1/4 0 

P78957W 01/17/1989 Complete BP America Production Co. MON 017N 092W 28 SW1/4SW1/4 0 

P83907W 11/01/1990 Complete BP America Production Co. STK 017N 092W 33 SE1/4NE1/4 6 

P170522W 09/02/2005 -- BP America Production Co. CBM 017N 092W 34 NW1/4NE1/4 58 

P170523W 09/02/2005 -- BP America Production Co. CBM 017N 092W 34 SE1/4NE1/4 58 P170524W 09/02/2005 -- BP America Production Co. CBM 017N 092W 34 NW1/4SE1/4 58 

P170525W 09/02/2005 -- BP America Production Co. CBM 017N 092W 34 SE1/4SE1/4 58 

P170527W 09/02/2005 -- BP America Production Co. CBM 017N 092W 35 SE1/4SW1/4 58 

P170528W 09/02/2005 -- BP America Production Co. CBM 017N 092W 35 NW1/4SE1/4 58 

P170529W 09/02/2005 -- BP America Production Co. CBM 017N 092W 35 SE1/4SE1/4 58 

P170887W 10/14/2005 -- BP America Production Co. CBM 017N 092W 35 NW1/4NE1/4 58 

P170888W 10/14/2005 -- BP America Production Co. CBM 017N 092W 35 SE1/4NE1/4 58 P170889W 10/14/2005 -- BP America Production Co. CBM 017N 092W 35 NW1/4NW1/4 58 

P170890W 10/14/2005 -- BP America Production Co. CBM 017N 092W 35 SE1/4NW1/4 58 

P171981W 11/30/2005 -- BP America Production Co. MIS 017N 093W 3 SW1/4SW1/4 150 P184334W 12/17/2007 Incomplete BP America Production Co. MIS 017N 093W 3 NW1/4NE1/4 100 

P171980W 11/30/2005 -- BP America Production Co. MIS 017N 093W 10 SW1/4NW1/4 150 

P64310W 06/09/1983 Complete BP America Production Co. STK 017N 093W 15 SW1/4NW1/4 7 1,

P139581W 07/03/2001 -- BP America Production Co. MIS 017N 093W 21 NW1/4SW1/4 0 

P177391W 09/15/2006 -- BP America Production Co. MIS 017N 093W 21 NW1/4SW1/4 200 

P183109W 06/04/2007 Incomplete BP America Production Co. MIS 017N 093W 21 NW1/4SW1/4 0 

P174021W 04/06/2006 -- BP America Production Co. MIS 017N 093W 25 SW1/4SW1/4 100 

P175189W 04/19/2006 -- BP America Production Co. MIS 017N 093W 27 NW1/4SE1/4 150 

P171984W 12/01/2005 -- BP America Production Co. MIS 017N 093W 31 NE1/4SW1/4 50 

P133868W 04/02/2001 -- BP America Production Co. MIS 017N 093W 35 SW1/4SW1/4 150 

P64311W 06/09/1983 Complete BP America Production Co. STK 017N 093W 35 SW1/4SW1/4 7 1,

P17370P 10/26/1967 Complete BP America Production Co. STK 017N 094W 4 NW1/4NW1/4 5 

P152045W 06/18/2003 -- BP America Production Co. MIS 017N 094W 9 NW1/4SW1/4 80 

P154978W 10/31/2003 -- BP America Production Co. MIS 017N 094W 13 NW1/4SW1/4 50 

P176012W 04/19/2006 Complete BP America Production Co. MIS 017N 094W 13 NW1/4SW1/4 150 

P194217W 11/15/2010 Complete BP America Production Co. MIS 017N 094W 13 NW1/4SW1/4 150 

P152753W 07/30/2003 Complete BP America Production Co. STK 017N 094W 19 SW1/4SW1/4 12 

P71969W 10/23/1985 Complete BP America Production Co. STK 017N 094W 21 SE1/4SW1/4 25 

P17371P 10/26/1967 Complete BP America Production Co. STK 017N 094W 26 NE1/4NE1/4 5 

P89063W 04/14/1992 Complete BP America Production Co. DOM 017N 094W 27 NE1/4NE1/4 10 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P187982W 06/02/2008 Incomplete BP America Production Co. MIS; MIS 017N 095W 1 SW1/4NW1/4 80 

P183450W 08/31/2007 -- BP America Production Co. MIS 017N 095W 2 NW1/4SE1/4 200 

P191484W 09/25/2009 Incomplete BP America Production Co. STK 017N 095W 5 SE1/4SW1/4 25 

P152752W 07/30/2003 -- BP America Production Co. STK 017N 095W 13 NE1/4SW1/4 25 

P173027W 01/19/2006 -- BP America Production Co. MIS 017N 095W 18 SW1/4NE1/4 60 1,

P188950W 09/19/2008 Fully Adjudicated BP America Production Co. MIS 018N 092W 1 NW1/4SE1/4 50 

P189034W 10/07/2008 Fully Adjudicated BP America Production Co. MIS 018N 092W 3 NE1/4SE1/4 50 

P186057W 03/12/2008 Incomplete BP America Production Co. MIS 018N 092W 7 SW1/4NE1/4 50 

P135632W 06/06/2001 -- BP America Production Co. MIS 018N 092W 9 SE1/4NW1/4 50 

P187974W 08/19/2008 Incomplete BP America Production Co. MIS; MIS 018N 092W 11 SW1/4NE1/4 50 

P175171W 05/12/2006 -- BP America Production Co. MIS 018N 092W 16 NE1/4SE1/4 200 

P191991W 10/09/2009 Complete BP America Production Co. MIS 018N 092W 19 NE1/4SW1/4 50 

P185940W 02/06/2008 Incomplete BP America Production Co. MIS 018N 092W 21 NE1/4SW1/4 50 

P188725W 08/22/2008 Incomplete BP America Production Co. MIS 018N 092W 23 SW1/4NW1/4 50 

P101327W 11/29/1995 Complete BP America Production Co. STK 018N 092W 25 SW1/4SE1/4 6 

P105038W 02/24/1997 Incomplete BP America Production Co. MIS 018N 092W 30 SW1/4SE1/4 70 

P149038W 01/29/2003 Complete BP America Production Co. MIS 018N 092W 30 SW1/4SE1/4 70 

P100202W 09/05/1995 Complete BP America Production Co. STK 018N 092W 31 SW1/4SW1/4 25 

P111248W 07/23/1998 Incomplete BP America Production Co. MIS 018N 092W 34 NW1/4SE1/4 

P101328W 11/29/1995 Complete BP America Production Co. STK 018N 093W 1 SW1/4SW1/4 6 

P157786W 04/09/2004 -- BP America Production Co. MIS 018N 093W 1 SW1/4SW1/4 150 

P189473W 12/29/2008 Unadjudicated BP America Production Co. MIS 018N 093W 1 SW1/4SW1/4 150 

P156487W 01/27/2004 Complete BP America Production Co. STK 018N 093W 2 SW1/4NW1/4 5 

P70757W 07/29/1985 Complete BP America Production Co. STK 018N 093W 3 SW1/4SW1/4 25 

P182024W 05/24/2007 Complete BP America Production Co. MIS 018N 093W 5 SW1/4NE1/4 100 

P66393W 02/15/1984 Complete BP America Production Co. STK 018N 093W 5 NW1/4SW1/4 10 

P64538W 06/24/1983 Complete BP America Production Co. STK 018N 093W 9 NW1/4SW1/4 5 

P156486W 01/27/2004 Complete BP America Production Co. STK 018N 093W 10 SW1/4NW1/4 5 

P70758W 07/29/1985 Complete BP America Production Co. STK 018N 093W 11 SE1/4SW1/4 12 

P101324W 11/29/1995 Complete BP America Production Co. STK 018N 093W 13 SE1/4SE1/4 25 

P101329W 11/29/1995 Complete BP America Production Co. STK 018N 093W 15 NE1/4SW1/4 5 

P131973W 01/16/2001 -- BP America Production Co. MIS 018N 093W 15 SE1/4NW1/4 0 

P173073W 02/10/2006 -- BP America Production Co. MIS 018N 093W 15 SE1/4NW1/4 50 

P64537W 06/24/1983 Complete BP America Production Co. STK 018N 093W 17 SW1/4SW1/4 10 P180338W 03/07/2007 Complete BP America Production Co. MIS 018N 093W 21 SE1/4SW1/4 60 

P64536W 06/24/1983 Complete BP America Production Co. STK 018N 093W 21 SE1/4SW1/4 20 

P70759W 07/29/1985 Complete BP America Production Co. STK 018N 093W 23 SW1/4SW1/4 12 

P182022W 05/24/2007 -- BP America Production Co. MIS 018N 093W 25 NW1/4SE1/4 100 

P120119W 10/29/1999 -- BP America Production Co. MIS 018N 093W 27 SW1/4SW1/4 150 

P66579W 03/15/1984 Complete BP America Production Co. STK 018N 093W 27 SW1/4SW1/4 8 

F-36 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P66578W 03/15/1984 Complete BP America Production Co. STK 018N 093W 29 SW1/4SW1/4 8 

P168408W 06/07/2005 -- BP America Production Co. MIS 018N 093W 33 SW1/4SW1/4 50 

P66580W 03/15/1984 Complete BP America Production Co. STK 018N 093W 33 NW1/4SW1/4 6 

P180336W 03/07/2007 -- BP America Production Co. MIS 018N 093W 34 SW1/4SW1/4 60 

P183110W 06/04/2007 Incomplete BP America Production Co. MIS 018N 093W 34 SW1/4SW1/4 0 

P194745W 01/05/2011 Complete BP America Production Co. MIS 018N 093W 35 SW1/4SW1/4 50 

P17373P 10/26/1967 Complete BP America Production Co. STK 018N 094W 22 SE1/4SE1/4 5 

P194748W 01/13/2011 Incomplete BP America Production Co. MIS 018N 094W 25 SE1/4NW1/4 100 

P175367W 07/11/2006 -- BP America Production Co. MIS 018N 094W 28 NE1/4SW1/4 25 

P165537W 02/23/2005 -- BP America Production Co. MIS 018N 094W 31 NW1/4NE1/4 50 

P165337W 02/10/2005 -- BP America Production Co. MIS 018N 094W 33 NE1/4SW1/4 50 

P158015W 04/13/2004 Complete BP America Production Co. STK 018N 095W 1 SE1/4SW1/4 14 P154377W 10/06/2003 Complete BP America Production Co. STK 018N 095W 7 SE1/4SW1/4 12 P158016W 04/13/2004 Complete BP America Production Co. STK 018N 095W 11 SE1/4SW1/4 12 P175170W 05/12/2006 -- BP America Production Co. MIS 018N 095W 14 SE1/4NE1/4 200 

P175201W 06/13/2006 -- BP America Production Co. MIS 018N 095W 18 SE1/4SE1/4 200 

P152778W 07/02/2003 -- BP America Production Co. MIS 018N 095W 19 SE1/4SW1/4 200 

P190924W 07/01/2009 Complete BP America Production Co. MIS 018N 095W 19 SE1/4SW1/4 75 

P178687W 11/16/2006 -- BP America Production Co. MIS 018N 095W 22 NW1/4NW1/4 200 

P191486W 09/25/2009 Incomplete BP America Production Co. STK 018N 095W 35 SW1/4SE1/4 25 P105059W 02/21/1997 Complete BP America Production Co. STK 018N 096W 1 NW1/4NW1/4 15 

P194620W 12/20/2010 Incomplete BP America Production Co. STK 018N 096W 7 NE1/4NW1/4 25 

P63762W 03/03/1983 Complete BP America Production Co. STK 018N 096W 13 NE1/4SW1/4 2 

P152923W 08/07/2003 -- BP America Production Co. MIS 018N 096W 15 NW1/4NW1/4 150 

P74149W 02/27/1987 Complete BP America Production Co. STK 018N 096W 20 SE1/4SE1/4 25 

P50386W 10/22/1979 Complete BP America Production Co. STK 018N 096W 23 SW1/4SW1/4 15 

P105058W 02/21/1997 Complete BP America Production Co. STK 018N 096W 27 SW1/4SE1/4 0.5 P153419W 08/20/2003 Complete BP America Production Co. STK 018N 096W 31 SW1/4SW1/4 10 

P178994W 11/22/2006 -- BP America Production Co. MIS 018N 096W 31 SW1/4SW1/4 80 

P11C 10/03/1945 Incomplete BP America Production Co. IND 018N 098W 1 NW1/4NW1/4 14 

P142768W 10/26/2001 Complete BP America Production Co. MIS 018N 098W 1 NW1/4NW1/4 180 2,

P26031W 01/22/1974 Fully Adjudicated BP America Production Co. MIS 018N 098W 1 NW1/4NE1/4 13 

P1883W 03/23/1967 -- BP America Production Co. IND 018N 099W 1 NW1/4SE1/4 468 4,

P6419P 05/31/1962 Complete BP America Production Co. STK 019N 091W 5 NW1/4NW1/4 7.5 

P128687W 09/05/2000 Complete BP America Production Co. STK 019N 091W 7 NW1/4NW1/4 25 

P138467W 08/29/2001 Complete BP America Production Co. STK 019N 091W 7 NW1/4NW1/4 5 

P141758W 01/07/2002 Complete BP America Production Co. STK 019N 091W 9 NE1/4NE1/4 4 

P6416P 05/31/1962 Complete BP America Production Co. STK 019N 091W 11 SE1/4NW1/4 7.5 

P55868W 03/05/1981 Complete BP America Production Co. STK 019N 091W 35 SW1/4SE1/4 20 

P101390W 03/10/1994 Incomplete BP America Production Co. MIS 019N 092W 2 NW1/4SE1/4 300 3,

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P53684W 09/02/1980 Complete BP America Production Co. MON 019N 092W 3 SW1/4SW1/4 0 P53700W 09/02/1980 Complete BP America Production Co. MON 019N 092W 3 NE1/4SW1/4 0 

P101009W 12/01/1995 Complete BP America Production Co. STK 019N 092W 5 NW1/4SW1/4 25 

P149530W 02/27/2003 -- BP America Production Co. STK 019N 092W 6 NW1/4NE1/4 10 

P101008W 12/01/1995 Complete BP America Production Co. STK 019N 092W 7 SW1/4SW1/4 25 

P168057W 05/25/2005 -- BP America Production Co. MIS 019N 092W 7 SW1/4SW1/4 50 P53663W 09/02/1980 Complete BP America Production Co. MON 019N 092W 9 NE1/4NE1/4 0 

P53672W 09/02/1980 Complete BP America Production Co. MON 019N 092W 9 NE1/4NE1/4 0 

P53678W 09/02/1980 Complete BP America Production Co. MON 019N 092W 9 NE1/4NE1/4 0 

P53679W 09/02/1980 Complete BP America Production Co. MON 019N 092W 9 NE1/4NE1/4 0 

P53681W 09/02/1980 Complete BP America Production Co. MON 019N 092W 9 NE1/4NE1/4 0 

P53687W 09/02/1980 Complete BP America Production Co. MON 019N 092W 9 NE1/4NE1/4 0 

P53637W 09/02/1980 Complete BP America Production Co. MON 019N 092W 11 NW1/4SW1/4 0 

P53659W 09/02/1980 Complete BP America Production Co. MON 019N 092W 11 NW1/4SW1/4 0 

P53660W 09/02/1980 Complete BP America Production Co. MON 019N 092W 11 SW1/4NW1/4 0 

P53682W 09/02/1980 Complete BP America Production Co. MON 019N 092W 11 NW1/4SW1/4 0 

P53644W 09/02/1980 Complete BP America Production Co. MON 019N 092W 13 SW1/4SE1/4 0 

P53653W 09/02/1980 Complete BP America Production Co. MON 019N 092W 15 SE1/4SE1/4 0 

P53654W 09/02/1980 Complete BP America Production Co. MON 019N 092W 15 SE1/4SE1/4 0 

P53655W 09/02/1980 Complete BP America Production Co. MON 019N 092W 15 SE1/4SE1/4 0 

P53656W 09/02/1980 Complete BP America Production Co. MON 019N 092W 15 SE1/4SE1/4 0 

P155406W 12/08/2003 -- BP America Production Co. MIS 019N 092W 17 NW1/4SW1/4 150 P53649W 09/02/1980 Complete BP America Production Co. MON 019N 092W 21 NE1/4NE1/4 0 

P53651W 09/02/1980 Complete BP America Production Co. MON 019N 092W 21 NE1/4NE1/4 0 

P53652W 09/02/1980 Complete BP America Production Co. MON 019N 092W 21 NE1/4NE1/4 0 

P149393W 11/25/2002 -- BP America Production Co. MIS 019N 092W 24 NW1/4SW1/4 100 

P187981W 06/02/2008 Incomplete BP America Production Co. MIS; MIS 019N 092W 27 SE1/4SW1/4 200 P53665W 09/02/1980 Complete BP America Production Co. MON 019N 092W 27 NE1/4NW1/4 0 P53666W 09/02/1980 Complete BP America Production Co. MON 019N 092W 27 NE1/4NW1/4 0 P53667W 09/02/1980 Complete BP America Production Co. MON 019N 092W 27 NE1/4NW1/4 0 

P53668W 09/02/1980 Complete BP America Production Co. MON 019N 092W 27 NE1/4NW1/4 0 

P187966W 07/23/2008 Incomplete BP America Production Co. MIS; MIS 019N 092W 29 NE1/4SW1/4 50 

P186603W 04/17/2008 Incomplete BP America Production Co. STK 019N 092W 35 NE1/4SW1/4 20 

P101326W 11/29/1995 Complete BP America Production Co. STK 019N 093W 1 NW1/4NE1/4 6 

P194807W 12/20/2010 Complete BP America Production Co. MIS 019N 093W 1 NE1/4NE1/4 80 

P97297W 10/06/1994 Incomplete BP America Production Co. IND; MIS 019N 093W 1 NW1/4SE1/4 20 

P177388W 09/08/2006 -- BP America Production Co. MIS 019N 093W 3 NE1/4SW1/4 50 

P183108W 06/04/2007 Incomplete BP America Production Co. MIS 019N 093W 3 NW1/4SW1/4 0 

P57683W 07/24/1981 Complete BP America Production Co. STK 019N 093W 3 NE1/4SW1/4 25 

P101325W 11/29/1995 Complete BP America Production Co. STK 019N 093W 7 SE1/4SW1/4 25 

F-38 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P100204W 09/05/1995 Complete BP America Production Co. STK 019N 093W 9 NW1/4SW1/4 25 

P126752W 07/05/2000 -- BP America Production Co. MIS 019N 093W 10 SW1/4SW1/4 40 

P57686W 07/24/1981 Complete BP America Production Co. STK 019N 093W 11 SW1/4SW1/4 25 

P126751W 07/05/2000 -- BP America Production Co. MIS 019N 093W 14 NE1/4SW1/4 40 

P57685W 07/24/1981 Complete BP America Production Co. STK 019N 093W 15 SE1/4SW1/4 25 

P101330W 11/29/1995 Complete BP America Production Co. STK 019N 093W 17 SE1/4SW1/4 6 

P136935W 07/24/2001 Fully Adjudicated BP America Production Co. MIS 019N 093W 19 SW1/4SE1/4 20 

P143131W 03/15/2002 Complete BP America Production Co. MON 019N 093W 19 SW1/4SE1/4 0 

P143132W 03/15/2002 Complete BP America Production Co. MON 019N 093W 19 NW1/4SE1/4 0 

P143133W 03/15/2002 Complete BP America Production Co. MON 019N 093W 19 SE1/4SE1/4 0 

P168348W 05/10/2005 -- BP America Production Co. MIS 019N 093W 19 NE1/4SW1/4 150 

P57681W 07/24/1981 Complete BP America Production Co. STK 019N 093W 21 NE1/4NE1/4 25 

P100205W 09/05/1995 Complete BP America Production Co. STK 019N 093W 29 NE1/4SW1/4 25 P100206W 09/05/1995 Complete BP America Production Co. STK 019N 093W 29 NE1/4SW1/4 25 P65191W 06/24/1983 Complete BP America Production Co. STK 019N 093W 31 NE1/4SW1/4 10 

P169650W 07/13/2005 -- BP America Production Co. MIS 019N 093W 33 SW1/4SW1/4 50 

P100203W 09/05/1995 Complete BP America Production Co. STK 019N 093W 35 SW1/4SW1/4 25 

P29066W 01/29/1975 Complete BP America Production Co. STK 019N 094W 5 NW1/4NW1/4 10 

P105068W 02/20/1997 Complete BP America Production Co. STK 019N 094W 13 SE1/4SW1/4 25 P107541W 09/18/1997 Complete BP America Production Co. MON 019N 094W 13 NE1/4NW1/4 0 

P107542W 09/18/1997 Complete BP America Production Co. MON 019N 094W 13 NW1/4NW1/4 0 P107543W 09/18/1997 Complete BP America Production Co. MON 019N 094W 13 NW1/4NW1/4 0 P107544W 09/18/1997 Complete BP America Production Co. MON 019N 094W 13 NW1/4NW1/4 0 P107545W 09/18/1997 Complete BP America Production Co. MON 019N 094W 13 NW1/4NW1/4 0 P91787W 05/21/1993 -- BP America Production Co. MON 019N 094W 14 SW1/4NE1/4 0 P91788W 05/21/1993 -- BP America Production Co. MON 019N 094W 14 NW1/4NE1/4 0 

P91789W 05/21/1993 -- BP America Production Co. MON 019N 094W 14 NE1/4NE1/4 0 

P95594W 05/26/1994 Complete BP America Production Co. MON 019N 094W 14 NE1/4NE1/4 0 

P95595W 05/26/1994 Complete BP America Production Co. MON 019N 094W 14 NW1/4NE1/4 0 

P95596W 05/26/1994 Complete BP America Production Co. MON 019N 094W 14 NE1/4NE1/4 0 

P173453W 02/28/2006 -- BP America Production Co. MIS 019N 094W 16 SE1/4SE1/4 100 

P54034W 10/06/1980 Complete BP America Production Co. STK 019N 094W 16 SW1/4NW1/4 2 

P54035W 10/06/1980 Complete BP America Production Co. STK 019N 094W 16 SW1/4SW1/4 1 

P98187W 01/10/1995 Complete BP America Production Co. STK 019N 094W 16 SW1/4NE1/4 25 1,0

P34378W 05/12/1976 Complete BP America Production Co. STK 019N 094W 19 SE1/4NE1/4 10 

P173331W 03/02/2006 -- BP America Production Co. MIS 019N 094W 23 SW1/4SW1/4 250 

P193315W 06/18/2010 Incomplete BP America Production Co. MIS 019N 094W 23 NW1/4SW1/4 50 

P71927W 02/03/1986 Complete BP America Production Co. STK 019N 094W 23 NW1/4SW1/4 10 

P188949W 09/19/2008 Fully Adjudicated BP America Production Co. MIS 019N 094W 31 SE1/4SW1/4 50 

P17496P 10/26/1967 Complete BP America Production Co. STK 019N 094W 34 SW1/4SW1/4 5 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P26024W 02/27/1974 -- BP America Production Co. DOM; IRR 019N 095W 1 NW1/4NW1/4 10 

P146658W 08/30/2002 Complete BP America Production Co. MON 019N 095W 4 SE1/4NW1/4 0 

P14942W 07/10/1972 Fully Adjudicated BP America Production Co. MIS 019N 095W 4 SW1/4NW1/4 9.5 P110553W 06/15/1998 -- BP America Production Co. DOM; STK 019N 095W 5 NE1/4NE1/4 25 P146664W 08/30/2002 Complete BP America Production Co. MON 019N 095W 5 SE1/4NE1/4 0 

P6209W 07/29/1970 Complete BP America Production Co. DOM 019N 095W 5 SE1/4NE1/4 10 

P84281W 01/15/1991 Complete BP America Production Co. MON 019N 095W 5 SE1/4NE1/4 0 

P84282W 01/15/1991 Complete BP America Production Co. MON 019N 095W 5 SE1/4NE1/4 0 

P84283W 01/15/1991 Complete BP America Production Co. MON 019N 095W 5 SE1/4NE1/4 0 

P183453W 09/05/2007 Incomplete BP America Production Co. MIS 019N 095W 6 SE1/4SE1/4 25 

P183454W 09/05/2007 Incomplete BP America Production Co. MIS 019N 095W 6 SE1/4SE1/4 50 

P183455W 09/05/2007 Incomplete BP America Production Co. MIS 019N 095W 6 SE1/4SE1/4 75 

P38913W 06/28/1977 Complete BP America Production Co. DOM 019N 095W 6 SE1/4NW1/4 10 

P39016W 06/20/1977 Complete BP America Production Co. DOM 019N 095W 6 SW1/4SE1/4 12.1 P43515W 05/24/1978 Complete BP America Production Co. DOM 019N 095W 6 SW1/4NW1/4 12 

P49641W 08/27/1979 Complete BP America Production Co. DOM 019N 095W 6 NE1/4SE1/4 20 

P51482W 03/11/1980 Complete BP America Production Co. DOM; STK 019N 095W 6 SW1/4NW1/4 20 P65306W 08/16/1983 Complete BP America Production Co. DOM 019N 095W 6 NE1/4NW1/4 10 

P70476W 06/13/1985 Complete BP America Production Co. DOM 019N 095W 6 NE1/4NE1/4 25 P189613W 01/07/2009 Complete BP America Production Co. MIS 019N 095W 11 SE1/4SW1/4 75 

P33378W 05/12/1976 Complete BP America Production Co. STK 019N 095W 11 NE1/4NE1/4 15 

P132358W 01/29/2001 -- BP America Production Co. MIS 019N 095W 13 NE1/4SE1/4 0 

P173455W 02/28/2006 -- BP America Production Co. MIS; STK 019N 095W 13 NE1/4SE1/4 100 1,

P152925W 08/07/2003 -- BP America Production Co. MIS 019N 095W 21 NE1/4SW1/4 85 

P188948W 09/18/2008 Complete BP America Production Co. MIS 019N 095W 21 NE1/4SW1/4 150 

P17492W 12/20/1972 Complete BP America Production Co. STK 019N 095W 22 SE1/4NW1/4 5 P17497P 10/26/1967 Complete BP America Production Co. STK 019N 095W 24 SE1/4SE1/4 5 

P168155W 06/08/2005 -- BP America Production Co. DOM 019N 096W 1 NE1/4NW1/4 25 

P181365W 05/08/2007 -- BP America Production Co. DOM 019N 096W 1 NW1/4SW1/4 25 

P56977W 06/02/1981 Complete BP America Production Co. DOM 019N 096W 1 SW1/4NW1/4 15 

P60980W 04/16/1982 Complete BP America Production Co. DOM 019N 096W 1 NW1/4NE1/4 10 

P34809W 08/19/1976 Complete BP America Production Co. DOM 019N 096W 2 NW1/4SE1/4 12 

P37180W 03/17/1977 -- BP America Production Co. MIS 019N 096W 2 NW1/4SE1/4 20 

P59057W 09/24/1981 Complete BP America Production Co. STK 019N 096W 2 NE1/4NE1/4 25 

P80506W 08/17/1989 Complete BP America Production Co. DOM 019N 096W 2 NE1/4NE1/4 0 P84603W 03/12/1991 Complete BP America Production Co. DOM; STK 019N 096W 2 NE1/4NE1/4 20 P40865W 11/10/1977 Fully Adjudicated BP America Production Co. MIS 019N 096W 7 NW1/4NE1/4 5 P66930W 04/09/1984 Fully Adjudicated BP America Production Co. MIS 019N 096W 7 NW1/4NE1/4 0 P153420W 08/20/2003 Complete BP America Production Co. STK 019N 096W 13 SE1/4NW1/4 10 

P63763W 03/03/1983 Complete BP America Production Co. STK 019N 096W 15 NW1/4NW1/4 20 

F-40 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P32764W 04/02/1976 Complete BP America Production Co. STK 019N 096W 17 SW1/4NW1/4 3 

P9626W 07/01/1971 Complete BP America Production Co. DOM 019N 096W 18 NW1/4NE1/4 7 P9627W 07/01/1971 Complete BP America Production Co. DOM 019N 096W 18 SE1/4NW1/4 8 

P50799W 12/19/1979 Complete BP America Production Co. STK 019N 096W 19 NE1/4SE1/4 3 

P189644W 01/15/2009 Incomplete BP America Production Co. MIS 019N 096W 20 SE1/4SE1/4 0 

P50385W 10/22/1979 Complete BP America Production Co. STK 019N 096W 21 NE1/4SE1/4 12 

P61410W 07/19/1982 Complete BP America Production Co. STK 019N 096W 23 SE1/4SW1/4 5 

P48828W 06/27/1979 Complete BP America Production Co. STK 019N 096W 31 NE1/4NE1/4 2 

P69128W 12/06/1984 Complete BP America Production Co. STK 019N 097W 1 NE1/4SW1/4 25 

P11767P 07/31/1964 Complete BP America Production Co. DOM; STK 019N 097W 3 NE1/4SE1/4 25 

P111931W 09/30/1998 Incomplete BP America Production Co. MIS 019N 097W 4 SW1/4SW1/4 60 1,

P11766P 07/31/1964 Complete BP America Production Co. DOM; STK 019N 097W 11 NW1/4SW1/4 25 

P50388W 10/22/1979 Complete BP America Production Co. STK 019N 097W 13 NE1/4SE1/4 5 

P158802W 04/30/2004 Complete BP America Production Co. STK 019N 097W 14 NE1/4NW1/4 12 

P150183W 03/10/2003 Incomplete BP America Production Co. MIS 019N 097W 19 NW1/4SW1/4 80 

P194161W 10/13/2010 Incomplete BP America Production Co. IND 019N 097W 19 SE1/4SE1/4 80 

P194162W 10/13/2010 Incomplete BP America Production Co. IND 019N 097W 19 NW1/4SE1/4 85 

P194163W 10/13/2010 Incomplete BP America Production Co. IND 019N 097W 19 SE1/4NE1/4 80 

P50387W 10/22/1979 Complete BP America Production Co. STK 019N 097W 19 SW1/4NE1/4 10 

P9630W 07/01/1971 Complete BP America Production Co. DOM 019N 097W 19 NW1/4NW1/4 5 

P74518W 04/23/1987 Complete BP America Production Co. STK 019N 097W 21 SE1/4NE1/4 2 

P142883W 02/26/2002 Complete BP America Production Co. STK 019N 097W 25 NE1/4NE1/4 3 

P163777W 11/17/2004 -- BP America Production Co. MON 019N 098W 22 SE1/4NE1/4 0 

P148445W 12/11/2002 Complete BP America Production Co. MON 019N 098W 23 SW1/4NW1/4 0 

P148446W 12/11/2002 Complete BP America Production Co. MON 019N 098W 23 SW1/4NE1/4 0 

P148447W 12/11/2002 Complete BP America Production Co. MON 019N 098W 23 NW1/4SE1/4 0 

P148448W 12/11/2002 Complete BP America Production Co. MON 019N 098W 23 NE1/4SW1/4 0 

P148449W 12/11/2002 Complete BP America Production Co. MON 019N 098W 23 SE1/4NW1/4 0 

P163770W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 SW1/4NE1/4 0 P163771W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 NE1/4NE1/4 0 

P163772W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 NW1/4NE1/4 0 P163773W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 SE1/4NW1/4 0 

P163774W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 NE1/4NW1/4 0 P163775W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 NW1/4NE1/4 0 P163776W 11/17/2004 -- BP America Production Co. MON 019N 098W 23 SW1/4NE1/4 0 

P169635W 09/06/2005 Unadjudicated BP America Production Co. 

MIS; MIS; MIS 019N 098W 23 SE1/4NW1/4 60 

P34816W 08/23/1976 Fully Adjudicated BP America Production Co. IND; MIS 019N 098W 23 SW1/4NE1/4 50 P37252W 03/31/1977 Fully Adjudicated BP America Production Co. MIS 019N 098W 23 NW1/4SE1/4 30 P52803W 06/25/1980 Fully Adjudicated BP America Production Co. IND 019N 098W 23 SW1/4NE1/4 50 P59378W 01/04/1982 Fully Adjudicated BP America Production Co. IND 019N 098W 23 SW1/4NE1/4 55 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P64759W 04/01/1983 BP America Production Co. MIS 019N 098W 23 SW1/4NE1/4 0 P64760W 04/01/1983 Fully Adjudicated BP America Production Co. MIS 019N 098W 23 NW1/4SE1/4 0 P64762W 04/01/1983 Fully Adjudicated BP America Production Co. MIS 019N 098W 23 SW1/4NE1/4 0 P64763W 04/01/1983 Fully Adjudicated BP America Production Co. MIS 019N 098W 23 SW1/4NE1/4 0 CR UW04/206 08/23/1976 -- BP America Production Co. IND 019N 098W 23 SW1/4NE1/4 50 

CR UW04/207 03/31/1977 -- BP America Production Co. IND 019N 098W 23 NW1/4SE1/4 30 

CR UW04/208 08/23/1976 -- BP America Production Co. IND 019N 098W 23 NE1/4SW1/4 50 

CR UW04/212 06/25/1980 -- BP America Production Co. IND 019N 098W 23 SW1/4NE1/4 50 

CR UW05/141 01/04/1982 -- BP America Production Co. IND 019N 098W 23 SW1/4NE1/4 55 

P74517W 04/23/1987 Complete BP America Production Co. STK 019N 098W 33 NW1/4NW1/4 5 P38641W 07/05/1977 Complete BP America Production Co. STK 019N 098W 35 NW1/4NE1/4 10 

P108008W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P108009W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P108010W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P108011W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P108012W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P108013W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NE1/4SE1/4 0 P108014W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NE1/4SE1/4 0 P108015W 11/03/1997 Complete BP America Production Co. MON 019N 099W 25 NE1/4SE1/4 0 P113569W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113570W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113571W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113572W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113573W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113574W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113575W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113576W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113577W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113578W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113579W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113580W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113589W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113590W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113592W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113596W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113597W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113598W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113599W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113600W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P113601W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

F-42 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P113603W 01/20/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116942W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116943W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116944W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116945W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116946W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116947W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116948W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116949W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116950W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P116951W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116952W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116953W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116954W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116955W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116956W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116957W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116958W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116959W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116960W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116961W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NE1/4SE1/4 0 P116962W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NE1/4SE1/4 0 P116963W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116964W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116965W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116966W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116968W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116969W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116970W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116971W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4NE1/4 0 

P116972W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SE1/4NE1/4 0 P116973W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116974W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 P116975W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P116976W 07/06/1999 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P126180W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126181W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P126182W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126183W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P126184W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P126185W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126186W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126187W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126188W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 NE1/4SE1/4 0 P126189W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SW1/4SE1/4 0 

P126190W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126191W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126192W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126193W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P126194W 06/09/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P127532W 08/03/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P128402W 08/21/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P128403W 08/21/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P128404W 08/21/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P128405W 08/21/2000 Complete BP America Production Co. MON 019N 099W 25 SE1/4SE1/4 0 

P138366W 08/22/2001 Complete BP America Production Co. MON 019N 099W 25 SW1/4SW1/4 0 

P160772W 06/21/2004 -- BP America Production Co. IND; MIS 019N 099W 25 SW1/4SE1/4 50 

P86107W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86109W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86110W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86111W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86112W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86113W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86114W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86115W 09/12/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86703W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86704W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86705W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86706W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86707W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86708W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86709W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86710W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P86711W 12/05/1991 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P95232W 04/20/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P95233W 04/20/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P95234W 04/20/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P95235W 04/20/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P95307W 05/02/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P95308W 05/02/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

F-44 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P95309W 05/02/1994 Complete BP America Production Co. MON 019N 099W 25 NW1/4SE1/4 0 

P129945W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129946W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129947W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129948W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129949W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129950W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129951W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129952W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129953W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 

P129954W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129955W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129956W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129957W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P129958W 10/12/2000 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P138367W 08/22/2001 Complete BP America Production Co. MON 019N 099W 36 SW1/4NE1/4 0 P138368W 08/22/2001 Complete BP America Production Co. MON 019N 099W 36 NW1/4NE1/4 0 P146198W 07/30/2002 Complete BP America Production Co. MON 019N 099W 36 NE1/4NW1/4 0 P146199W 07/30/2002 Complete BP America Production Co. MON 019N 099W 36 SE1/4NE1/4 0 P146200W 07/30/2002 Complete BP America Production Co. MON 019N 099W 36 SE1/4NW1/4 0 

P39826W 07/15/1977 Complete BP America Production Co. STK 020N 090W 31 SW1/4NW1/4 5 

P17376P 06/30/1966 Complete BP America Production Co. STK 020N 090W 34 NW1/4NE1/4 5 

P39827W 07/15/1977 Complete BP America Production Co. STK 020N 090W 34 SW1/4NE1/4 5 

P6414P 05/31/1963 Complete BP America Production Co. DOM; STK 020N 091W 18 NE1/4SW1/4 7.5 

P99499W 06/09/1995 Complete BP America Production Co. STK 020N 091W 18 SW1/4SW1/4 20 

P111868W 09/21/1998 Complete BP America Production Co. STK 020N 091W 19 SE1/4NE1/4 4 P53645W 09/02/1980 Complete BP America Production Co. MON 020N 091W 19 SE1/4NW1/4 0 

P6412P 05/31/1963 Complete BP America Production Co. STK 020N 091W 21 NW1/4SE1/4 7.5 

P111869W 09/21/1998 Complete BP America Production Co. STK 020N 091W 23 NW1/4SE1/4 4 P6420P 05/31/1963 Complete BP America Production Co. STK 020N 091W 33 NE1/4NW1/4 7.5 

P6413P 05/31/1962 Complete BP America Production Co. STK 020N 091W 35 SW1/4NE1/4 7.5 

P142885W 02/26/2002 -- BP America Production Co. STK 020N 092W 1 SW1/4NW1/4 25 

P129280W 09/25/2000 Complete BP America Production Co. STK 020N 092W 7 NW1/4NE1/4 25 P14185W 06/01/1972 -- BP America Production Co. MIS 020N 092W 11 SW1/4NW1/4 25 

P82127W 04/09/1990 Incomplete BP America Production Co. MIS 020N 092W 11 SW1/4NE1/4 15 

P38499W 06/30/1977 Fully Adjudicated BP America Production Co. MIS 020N 092W 15 SW1/4SW1/4 5 

P40245W 08/30/1977 Fully Adjudicated BP America Production Co. MIS 020N 092W 15 SW1/4SW1/4 5 

P50797W 12/19/1979 Complete BP America Production Co. STK 020N 092W 19 NE1/4NE1/4 10 

P183655W 10/25/2007 -- BP America Production Co. MIS 020N 092W 20 NW1/4NW1/4 100 P53634W 09/02/1980 Complete BP America Production Co. MON 020N 092W 25 NW1/4SW1/4 0 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P53680W 09/02/1980 Complete BP America Production Co. MON 020N 092W 25 NW1/4SW1/4 0 

P53693W 09/02/1980 Complete BP America Production Co. MON 020N 092W 25 NW1/4SW1/4 0 

P53698W 09/02/1980 Complete BP America Production Co. MON 020N 092W 25 NW1/4SW1/4 0 

P53699W 09/02/1980 Complete BP America Production Co. MON 020N 092W 25 NW1/4SW1/4 0 

P53638W 09/02/1980 Complete BP America Production Co. MON 020N 092W 27 SE1/4SE1/4 0 

P53689W 09/02/1980 Complete BP America Production Co. MON 020N 092W 27 SE1/4SE1/4 0 

P53690W 09/02/1980 Complete BP America Production Co. MON 020N 092W 27 SE1/4SE1/4 0 

P53691W 09/02/1980 Complete BP America Production Co. MON 020N 092W 27 SE1/4SE1/4 0 

P53695W 09/02/1980 Complete BP America Production Co. MON 020N 092W 27 SE1/4SE1/4 0 

P53669W 09/02/1980 Complete BP America Production Co. MON 020N 092W 33 SE1/4SE1/4 0 

P53671W 09/02/1980 Complete BP America Production Co. MON 020N 092W 33 SE1/4SE1/4 0 

P53648W 09/02/1980 Complete BP America Production Co. MON 020N 092W 35 SW1/4SE1/4 0 

P53688W 09/02/1980 Complete BP America Production Co. MON 020N 092W 35 SW1/4SE1/4 0 

P53692W 09/02/1980 Complete BP America Production Co. MON 020N 092W 35 SW1/4SE1/4 0 

P191918W 12/04/2009 Incomplete BP America Production Co. MON 020N 093W 1 SE1/4NE1/4 0 P96912W 09/01/1994 -- BP America Production Co. MIS 020N 093W 4 SW1/4SW1/4 

P193634W 05/28/2010 Complete BP America Production Co. STK 020N 093W 5 SE1/4SW1/4 10 P63761W 03/03/1983 Complete BP America Production Co. STK 020N 093W 13 NW1/4SW1/4 10 

P170571W 10/04/2005 -- BP America Production Co. MIS 020N 093W 20 SE1/4NE1/4 150 

P18226P 09/15/1965 Complete BP America Production Co. STK 020N 093W 20 NW1/4NW1/4 15 

P194472W 12/02/2010 Complete BP America Production Co. MIS 020N 093W 21 SE1/4SW1/4 50 

P50389W 10/22/1979 Complete BP America Production Co. STK 020N 093W 23 SE1/4NE1/4 2 

P178317W 09/07/2006 Complete BP America Production Co. MIS 020N 093W 25 SE1/4SW1/4 50 

P192145W 02/04/2010 Complete BP America Production Co. MIS 020N 093W 25 SE1/4SW1/4 50 

P152042W 06/05/2003 -- BP America Production Co. MIS 020N 093W 27 SW1/4SW1/4 200 

P50798W 12/19/1979 Complete BP America Production Co. STK 020N 093W 29 NE1/4SE1/4 5 

P183319W 07/18/2007 -- BP America Production Co. STK 020N 093W 31 NE1/4SW1/4 25 

P50390W 10/22/1979 Complete BP America Production Co. STK 020N 093W 35 NE1/4NE1/4 15 

P139579W 07/03/2001 -- BP America Production Co. MIS 020N 094W 7 SW1/4NE1/4 0 

P164756W 01/25/2005 Complete BP America Production Co. MIS 020N 094W 7 SW1/4NE1/4 50 

P94775W 03/24/1994 Incomplete BP America Production Co. MIS; STK 020N 094W 7 SE1/4SE1/4 60 10,

P14750W 07/21/1972 Complete BP America Production Co. STK 020N 094W 8 NW1/4SW1/4 10 

P184333W 12/17/2007 Incomplete BP America Production Co. MIS 020N 094W 9 NW1/4SE1/4 50 

P59219W 01/05/1982 Complete BP America Production Co. STK 020N 094W 9 NW1/4SE1/4 15 

P29065W 01/29/1975 Complete BP America Production Co. STK 020N 094W 11 SW1/4SE1/4 10 

P263W 11/12/1959 Complete BP America Production Co. STK 020N 094W 15 SE1/4SE1/4 28 

P193303W 06/23/2010 Complete BP America Production Co. MIS 020N 094W 17 SE1/4NE1/4 50 

P7544P 12/31/1929 Complete BP America Production Co. STK 020N 094W 19 NW1/4SE1/4 15 

P189036W 10/07/2008 Fully Adjudicated BP America Production Co. MIS 020N 094W 20 SE1/4NW1/4 50 

P102711W 05/16/1996 Complete BP America Production Co. STK 020N 094W 22 NW1/4SW1/4 15 

F-46 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P113188W 11/25/1998 Complete BP America Production Co. MUN 020N 094W 22 SE1/4SW1/4 250 

P186502W 04/21/2008 Incomplete BP America Production Co. TST 020N 094W 22 NE1/4SW1/4 0 

P192719W 10/21/2009 Incomplete BP America Production Co. MUN 020N 094W 22 NE1/4SW1/4 400 

P7545P 03/23/1963 Complete BP America Production Co. STK 020N 094W 22 NW1/4SW1/4 10 

P35724W 12/17/1976 Complete BP America Production Co. STK 020N 094W 24 NW1/4SW1/4 6 

P132296W 01/19/2001 -- BP America Production Co. MON 020N 094W 27 SE1/4SW1/4 0 

P146655W 08/30/2002 Complete BP America Production Co. MON 020N 094W 27 SW1/4SE1/4 0 

P146657W 08/30/2002 Complete BP America Production Co. MON 020N 094W 27 NW1/4SW1/4 0 

P189429W 11/13/2008 Incomplete BP America Production Co. MIS 020N 094W 27 NE1/4NE1/4 75 

P192718W 10/02/2009 Incomplete BP America Production Co. MUN 020N 094W 27 NE1/4NE1/4 200 

P15644W 08/28/1972 Complete BP America Production Co. STK 020N 094W 30 SW1/4SE1/4 10 

P181641W 06/07/2007 Unadjudicated BP America Production Co. MIS 020N 094W 32 SW1/4NW1/4 40 

P59218W 01/05/1982 Complete BP America Production Co. STK 020N 094W 33 SE1/4NW1/4 12 

P117C 12/31/1898 Incomplete BP America Production Co. -- 020N 094W 34 NE1/4NE1/4 20 1,

P118C 05/04/1902 Incomplete BP America Production Co. MUN 020N 094W 34 SW1/4NE1/4 10 1,

P119C 01/15/1912 Incomplete BP America Production Co. MUN 020N 094W 34 NW1/4NE1/4 15 1,

P120C 08/20/1921 Incomplete BP America Production Co. MUN 020N 094W 34 NW1/4NE1/4 67 1,

P132295W 01/19/2001 -- BP America Production Co. MON 020N 094W 34 NE1/4NW1/4 0 P132297W 01/19/2001 -- BP America Production Co. MON 020N 094W 34 NE1/4NW1/4 0 

P146654W 08/30/2002 Complete BP America Production Co. MON 020N 094W 34 NE1/4NW1/4 0 

P150263W 04/02/2003 -- BP America Production Co. MIS 020N 094W 34 NE1/4NE1/4 100 

P17024P 10/24/1958 Complete BP America Production Co. DOM 020N 094W 34 NE1/4NW1/4 20 1,P177859W 09/19/2006 Complete BP America Production Co. MIS; STK 020N 094W 34 NW1/4SE1/4 80 1,

P41724W 02/06/1978 Fully Adjudicated BP America Production Co. MIS 020N 094W 34 NE1/4SE1/4 100 1,

P47788W 05/02/1979 -- BP America Production Co. MIS 020N 094W 34 SE1/4SE1/4 50 1,

P48097W 05/02/1979 Incomplete BP America Production Co. MIS 020N 094W 34 NE1/4SE1/4 46 1,P49765W 08/13/1979 Incomplete BP America Production Co. MIS 020N 094W 34 SE1/4SE1/4 20 1,P52858W 07/01/1980 Fully Adjudicated BP America Production Co. DOM; MIS 020N 094W 34 SE1/4SE1/4 10 

P56206W 06/08/1979 BP America Production Co. DOM; MIS 020N 094W 34 SE1/4SE1/4 60 1,P60649W 11/30/1981 Fully Adjudicated BP America Production Co. MIS 020N 094W 34 SW1/4SE1/4 150 1,

P695W 03/28/1961 -- BP America Production Co. DOM; IND; IRR; MIS 020N 094W 34 NW1/4NW1/4 250 1,

P70302W 02/28/1985 -- BP America Production Co. DOM; MIS 020N 094W 34 NE1/4SE1/4 25 1,

P84596W 06/29/1988 Incomplete BP America Production Co. MIS 020N 094W 34 NE1/4SE1/4 150 1,

P86244W 03/11/1991 Incomplete BP America Production Co. MIS 020N 094W 34 NE1/4SE1/4 25 1,

P97699W 11/03/1994 Complete BP America Production Co. MON 020N 094W 34 SE1/4SE1/4 0 

P97700W 11/03/1994 Complete BP America Production Co. MON 020N 094W 34 SE1/4SE1/4 0 

P97701W 11/03/1994 Complete BP America Production Co. MON 020N 094W 34 SE1/4SE1/4 0 

P97702W 11/03/1994 Complete BP America Production Co. MON 020N 094W 34 SE1/4SE1/4 0 

P97703W 11/03/1994 Complete BP America Production Co. MON 020N 094W 34 SE1/4SE1/4 0 

CR UW04/213 07/01/1980 -- BP America Production Co. DOM; MIS 020N 094W 34 SE1/4SE1/4 10 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P173330W 03/02/2006 -- BP America Production Co. MIS 020N 094W 35 NW1/4NW1/4 150 

P188087W 07/30/2008 Incomplete BP America Production Co. MIS; MIS 020N 094W 35 SE1/4NW1/4 175 

P189201W 10/15/2008 Incomplete BP America Production Co. MIS 020N 095W 7 SW1/4NE1/4 50 

P55030W 11/26/1980 -- BP America Production Co. DOM 020N 095W 7 SW1/4NE1/4 25 P144149W 04/23/2002 Complete BP America Production Co. DOM; STK 020N 095W 8 NW1/4SE1/4 14 

P144331W 05/06/2002 Complete BP America Production Co. DOM; STK 020N 095W 8 NE1/4SE1/4 14 

P189347W 10/31/2008 Incomplete BP America Production Co. DOM; STK 020N 095W 8 NW1/4NE1/4 25 

P42533W 03/20/1978 Complete BP America Production Co. DOM; STK 020N 095W 8 NE1/4NE1/4 5 P26025W 02/27/1974 Complete BP America Production Co. STK 020N 095W 11 SW1/4SW1/4 10 

P193949W 08/04/2010 Complete BP America Production Co. STK 020N 095W 13 NW1/4SE1/4 9 9,P106869W 07/16/1997 Incomplete BP America Production Co. MIS 020N 095W 16 SE1/4SE1/4 25 

P193882W 09/10/2010 Incomplete BP America Production Co. DOM; STK 020N 095W 17 NW1/4NW1/4 25 

P33697W 06/01/1976 Complete BP America Production Co. DOM; STK 020N 095W 17 NE1/4NW1/4 35 P69555W 01/07/1985 Complete BP America Production Co. DOM; STK 020N 095W 17 SE1/4SW1/4 25 

P7831W 01/26/1971 Complete BP America Production Co. STK 020N 095W 18 NE1/4SW1/4 25 9,P62636W 12/01/1982 Complete BP America Production Co. DOM 020N 095W 19 NW1/4SW1/4 10 

P43000W 04/28/1978 Incomplete BP America Production Co. DOM; MIS; STK 020N 095W 20 SW1/4NW1/4 8 

P44604W 08/10/1978 Complete BP America Production Co. DOM 020N 095W 20 SE1/4NW1/4 12 P99764W 07/21/1995 Complete BP America Production Co. DOM 020N 095W 20 NW1/4NW1/4 8 

P102712W 05/16/1996 Complete BP America Production Co. STK 020N 095W 21 NW1/4SE1/4 15 

P9963W 08/04/1971 Complete BP America Production Co. STK 020N 095W 21 NE1/4SE1/4 20 

P102804W 06/21/1996 Complete BP America Production Co. STK 020N 095W 23 NW1/4SE1/4 20 P59220W 01/05/1982 Complete BP America Production Co. STK 020N 095W 27 NE1/4SE1/4 15 

P7543P 12/31/1929 Complete BP America Production Co. STK 020N 095W 33 SW1/4SW1/4 15 P15643W 08/28/1972 Complete BP America Production Co. STK 020N 095W 35 SW1/4NE1/4 10 

P22968W 12/07/1972 Complete BP America Production Co. STK 020N 096W 10 SW1/4NW1/4 25 2,

P178351W 10/30/2006 -- BP America Production Co. MIS 020N 096W 12 NE1/4SW1/4 100 

P49642W 08/27/1979 Complete BP America Production Co. STK 020N 096W 13 SW1/4NE1/4 25 

P62810W 12/21/1982 Complete BP America Production Co. DOM 020N 096W 24 NW1/4SW1/4 10 

P63378W 03/08/1983 Complete BP America Production Co. DOM 020N 096W 24 NE1/4NW1/4 10 

P49643W 08/27/1979 Complete BP America Production Co. STK 020N 096W 25 NW1/4NE1/4 25 P49644W 08/27/1979 Complete BP America Production Co. DOM 020N 096W 26 SW1/4NW1/4 25 

P60892W 05/20/1982 Complete BP America Production Co. DOM 020N 096W 26 NW1/4NW1/4 10 

P63520W 03/01/1983 Complete BP America Production Co. DOM 020N 096W 26 NW1/4SE1/4 7 

P187202W 06/25/2008 Incomplete BP America Production Co. STK 020N 096W 35 NE1/4NW1/4 25 P187203W 06/25/2008 Incomplete BP America Production Co. DOM 020N 096W 35 SE1/4SW1/4 25 

P34057W 06/09/1976 Complete BP America Production Co. DOM 020N 096W 36 SE1/4NW1/4 20 

P57110W 06/02/1981 Complete BP America Production Co. DOM; STK 020N 096W 36 SE1/4NW1/4 20 

P64300W 06/07/1983 Complete BP America Production Co. DOM 020N 096W 36 NE1/4NW1/4 18 P82536W 05/24/1990 Complete BP America Production Co. STK 020N 096W 36 NW1/4SE1/4 7 

F-48 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P42290W 10/26/1977 Fully Adjudicated BP America Production Co. DOM; IRR; STK 020N 097W 1 NW1/4SW1/4 400 1,CR UW06/107 10/26/1977 -- BP America Production Co. DOM; IRR; STK 020N 097W 1 NW1/4SW1/4 400 

P158801W 04/30/2004 Complete BP America Production Co. STK 020N 097W 15 NW1/4SE1/4 6 

P104358W 10/21/1996 Incomplete BP America Production Co. MIS 020N 097W 27 NW1/4NE1/4 60 

P189038W 10/07/2008 Fully Adjudicated BP America Production Co. MIS 020N 097W 36 NE1/4SW1/4 120 

P148709W 12/26/2002 -- BP America Production Co. DOM; STK 021N 091W 9 SE1/4NW1/4 25 

P173344W 02/27/2006 -- BP America Production Co. STK 021N 091W 18 SE1/4NE1/4 25 

P38929W 06/22/1977 -- BP America Production Co. MIS 021N 091W 21 SE1/4SW1/4 0 

P108972W 03/02/1998 Complete BP America Production Co. DOM 021N 091W 26 NW1/4NW1/4 25 

P27102W 06/26/1974 Complete BP America Production Co. STK 021N 091W 30 NE1/4NE1/4 10 1,

P164449W 12/14/2004 -- BP America Production Co. DOM; STK 021N 091W 34 NW1/4SW1/4 25 

P35939W 01/19/1977 Complete BP America Production Co. STK 021N 092W 1 SE1/4SW1/4 5 

P56414W 04/10/1981 Complete BP America Production Co. STK 021N 092W 1 SE1/4SW1/4 10 

P177392W 09/15/2006 -- BP America Production Co. MIS 021N 092W 8 SE1/4SW1/4 200 

P140257W 10/18/2001 Complete BP America Production Co. STK 021N 092W 9 SW1/4SW1/4 9 

P142884W 02/26/2002 Complete BP America Production Co. STK 021N 092W 11 SE1/4SE1/4 5 

P45264W 09/26/1978 Complete BP America Production Co. STK 021N 092W 13 NE1/4SW1/4 4 

P140256W 10/18/2001 Complete BP America Production Co. MIS 021N 092W 19 SE1/4NW1/4 20 

P140255W 10/18/2001 Complete BP America Production Co. MIS 021N 092W 32 NE1/4SW1/4 20 1,

P63187W 02/01/1983 Complete BP America Production Co. STK 021N 092W 32 NE1/4SW1/4 20 1,

P144612W 05/23/2002 Complete BP America Production Co. STK 021N 092W 35 SE1/4SW1/4 10 P6384P 12/31/1933 Complete BP America Production Co. STK 021N 093W 1 NW1/4SW1/4 20 

P97904W 11/09/1994 -- BP America Production Co. MIS 021N 093W 5 SW1/4SW1/4 50 P6391P 12/31/1930 Complete BP America Production Co. STK 021N 093W 9 NE1/4NW1/4 25 

P6390P 12/31/1925 Complete BP America Production Co. STK 021N 093W 11 SW1/4NW1/4 20 

P174640W 01/19/2006 -- BP America Production Co. STK 021N 093W 17 SW1/4NE1/4 25 

P157244W 02/24/2004 -- BP America Production Co. MIS 021N 093W 23 SE1/4SW1/4 50 

P38302W 06/09/1977 Complete BP America Production Co. DOM; STK 021N 093W 29 NW1/4SW1/4 12 

P174639W 01/19/2006 -- BP America Production Co. STK 021N 093W 33 SE1/4NE1/4 25 

P189501W 11/24/2008 Incomplete BP America Production Co. MIS 021N 093W 35 NW1/4SW1/4 150 

P133248W 03/27/2001 -- BP America Production Co. MIS 021N 094W 3 NE1/4SW1/4 0 P194809W 12/20/2010 Complete BP America Production Co. MIS 021N 094W 3 NE1/4SW1/4 50 

P7540P 06/03/1965 Complete BP America Production Co. STK 021N 094W 19 SE1/4NE1/4 15 

P26026W 02/27/1974 Complete BP America Production Co. STK 021N 094W 21 SW1/4SE1/4 10 

P6385P 12/31/1935 Complete BP America Production Co. STK 021N 094W 23 NW1/4SE1/4 15 

P172629W 12/20/2005 -- BP America Production Co. MIS 021N 094W 26 NW1/4SE1/4 150 

P194165W 10/21/2010 Complete BP America Production Co. MIS 021N 094W 26 SW1/4NE1/4 50 

P193950W 08/04/2010 Complete BP America Production Co. STK 021N 094W 29 SW1/4SE1/4 14 

P14749W 07/21/1972 Complete BP America Production Co. STK 021N 094W 31 NE1/4NW1/4 5 

P33605W 06/09/1976 Complete BP America Production Co. STK 021N 094W 31 SE1/4SE1/4 10 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P68912W 10/30/1984 Complete BP America Production Co. STK 021N 094W 31 NE1/4NW1/4 14 

P7541P 12/31/1949 Complete BP America Production Co. STK 021N 094W 33 SE1/4SW1/4 15 P14278W 06/07/1972 Complete BP America Production Co. DOM; STK 021N 095W 5 NW1/4NW1/4 7 

P26615W 04/30/1974 Complete BP America Production Co. STK 021N 095W 9 NE1/4NE1/4 5 

P25053W 11/19/1973 Complete BP America Production Co. STK 021N 095W 17 SE1/4SE1/4 10 

P102713W 05/16/1996 Complete BP America Production Co. STK 021N 095W 19 SE1/4SW1/4 15 

P7539P 12/31/1944 Complete BP America Production Co. STK 021N 095W 23 SE1/4SE1/4 20 P84124W 12/10/1990 Complete BP America Production Co. STK 021N 095W 26 SE1/4SW1/4 15 

P7821W 12/15/1970 Complete BP America Production Co. STK 021N 095W 30 NE1/4SW1/4 25 9,P164658W 01/05/2005 -- BP America Production Co. MIS 021N 095W 34 NW1/4SW1/4 140 

P186747W 04/25/2008 Incomplete BP America Production Co. MIS 021N 095W 34 NW1/4SW1/4 140 

P7538P 12/31/1939 Complete BP America Production Co. STK 021N 095W 34 SW1/4NW1/4 10 

P165697W 03/21/2005 -- BP America Production Co. MIS 021N 096W 4 NE1/4SW1/4 200 

P106611W 06/30/1997 Incomplete BP America Production Co. MIS 021N 097W 35 NE1/4NE1/4 60 

P192788W 04/13/2010 Incomplete BP America Production Co. DOM; STK 022N 091W 9 SW1/4SE1/4 25 

P8459P 06/23/1967 Complete BP America Production Co. STK 022N 091W 15 NE1/4SE1/4 10 P80716W 09/18/1989 Complete BP America Production Co. DOM; STK 022N 091W 27 NE1/4SE1/4 16 P8458P 06/07/1953 Complete BP America Production Co. DOM; STK 022N 091W 27 NW1/4SW1/4 25 

P83544W 09/10/1990 Complete BP America Production Co. STK 022N 092W 12 SW1/4SW1/4 5 

P40644P 10/25/1977 Complete BP America Production Co. STK 022N 092W 15 SE1/4SE1/4 1 

P40645P 10/25/1977 Complete BP America Production Co. STK 022N 092W 27 SE1/4SW1/4 1 

P55208W 07/05/1979 Complete BP America Production Co. STK 022N 092W 29 NE1/4SW1/4 25 

P161084W 08/04/2004 -- BP America Production Co. MIS 022N 092W 35 NW1/4NW1/4 200 

P55207W 07/05/1979 Complete BP America Production Co. STK 022N 092W 35 SE1/4SW1/4 25 

P9820W 07/19/1971 Complete BP America Production Co. STK 022N 093W 10 NE1/4SW1/4 25 P55206W 07/05/1979 Complete BP America Production Co. STK 022N 093W 13 NW1/4SW1/4 25 

P161336W 08/12/2004 -- BP America Production Co. MIS 022N 093W 15 NW1/4NW1/4 200 

P5987W 07/10/1970 Complete BP America Production Co. STK 022N 093W 19 SW1/4NE1/4 10 

P6383P 12/31/1924 Complete BP America Production Co. STK 022N 093W 21 SW1/4SW1/4 10 P155607W 12/19/2003 -- BP America Production Co. MIS 022N 093W 25 NW1/4NW1/4 80 

P40647P 10/25/1977 Complete BP America Production Co. STK 022N 093W 25 NW1/4SE1/4 1 

P40646P 10/25/1977 Complete BP America Production Co. STK 022N 093W 29 SW1/4SW1/4 1 

P139354W 09/24/2001 -- BP America Production Co. MIS 022N 093W 32 SW1/4NE1/4 75 

P180894W 03/22/2007 -- BP America Production Co. MIS 022N 093W 32 SE1/4NW1/4 85 

P6382P 12/31/1916 Complete BP America Production Co. DOM; STK 022N 093W 32 NE1/4NE1/4 10 

P152233W 07/09/2003 -- BP America Production Co. STK 022N 093W 36 NE1/4NE1/4 25 

P16769W 11/29/1972 Complete BP America Production Co. STK 022N 093W 36 NE1/4NE1/4 25 

P144035W 04/23/2002 -- BP America Production Co. MIS 022N 094W 9 SW1/4SW1/4 50 

P174641W 01/19/2006 -- BP America Production Co. STK 022N 094W 9 NW1/4NE1/4 25 

P194811W 12/20/2010 Complete BP America Production Co. MIS 022N 094W 15 NW1/4SW1/4 50 1,

F-50 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P144036W 04/23/2002 BP America Production Co. MIS 022N 094W 17 SW1/4SW1/4 50 

P6386P 12/31/1930 Complete BP America Production Co. DOM; STK 022N 094W 18 SW1/4SW1/4 20 

P98626W 03/31/1995 Complete BP America Production Co. STK 022N 094W 18 SW1/4SW1/4 5 

P193743W 09/01/2010 Complete BP America Production Co. MIS 022N 094W 21 SW1/4SW1/4 50 1,

P146579W 08/22/2002 Complete BP America Production Co. MIS 022N 094W 22 NW1/4SW1/4 40 1,

P194808W 12/20/2010 Complete BP America Production Co. MIS 022N 094W 23 SE1/4SW1/4 50 

P144638W 05/31/2002 Complete BP America Production Co. MIS 022N 094W 28 SW1/4SW1/4 65 1,

P138671W 08/28/2001 -- BP America Production Co. MIS 022N 094W 29 SE1/4SW1/4 50 

P194810W 12/20/2010 Complete BP America Production Co. MIS 022N 094W 29 SE1/4SW1/4 50 

P99887W 07/27/1995 Incomplete BP America Production Co. MIS 022N 094W 34 SW1/4SW1/4 50 

P107546W 09/18/1997 Complete BP America Production Co. MON 022N 094W 35 SW1/4NW1/4 0 

P107547W 09/18/1997 Complete BP America Production Co. MON 022N 094W 35 SE1/4NW1/4 0 

P107548W 09/18/1997 Complete BP America Production Co. MON 022N 094W 35 SE1/4NW1/4 0 

P107549W 09/18/1997 Complete BP America Production Co. MON 022N 094W 35 SW1/4NW1/4 0 

P135750W 06/14/2001 Complete BP America Production Co. MON 022N 094W 35 SE1/4NW1/4 0 

P135751W 06/14/2001 Complete BP America Production Co. MON 022N 094W 35 SE1/4NW1/4 0 

P152924W 08/07/2003 -- BP America Production Co. MIS 022N 095W 5 NE1/4SW1/4 150 

P22748W 06/25/1973 Complete BP America Production Co. DOM; STK 022N 095W 7 NE1/4NW1/4 5 

P109956W 05/04/1998 -- BP America Production Co. MIS 022N 095W 11 NW1/4SE1/4 50 

P169649W 07/13/2005 -- BP America Production Co. MIS 022N 095W 11 NW1/4SE1/4 50 

P153998W 09/05/2003 -- BP America Production Co. STK 022N 095W 13 NW1/4SE1/4 25 

P171025W 10/21/2005 -- BP America Production Co. MIS 022N 095W 16 NE1/4NW1/4 200 

P183656W 10/25/2007 -- BP America Production Co. MIS 022N 095W 18 SE1/4SE1/4 120 

P33169W 05/07/1976 Complete BP America Production Co. DOM; STK 022N 095W 21 SE1/4NE1/4 5 P158019W 04/13/2004 Complete BP America Production Co. STK 022N 095W 28 SE1/4NE1/4 13 P64146W 05/23/1983 Complete BP America Production Co. STK 022N 095W 29 NW1/4NW1/4 18 

P33168W 05/07/1976 Complete BP America Production Co. DOM 022N 095W 35 SE1/4SE1/4 5 

P30390W 07/07/1975 Complete BP America Production Co. DOM 022N 096W 1 NE1/4NE1/4 10 P153994W 09/05/2003 Complete BP America Production Co. STK 022N 096W 11 SW1/4SW1/4 12 

P178919W 12/11/2006 Incomplete BP America Production Co. DOM; IRR; STK 022N 096W 15 NE1/4SE1/4 100 

P42749W 04/06/1978 -- BP America Production Co. DOM; STK 022N 096W 17 NW1/4SE1/4 25 P8466P 05/20/1968 Complete BP America Production Co. STK 023N 091W 3 NW1/4NW1/4 10 

P59387W 01/27/1982 Complete BP America Production Co. STK 023N 091W 10 SW1/4NE1/4 0 1,

P7349W 11/04/1970 Complete BP America Production Co. STK 023N 091W 10 SW1/4NE1/4 15 1,P8467P 05/25/1968 Complete BP America Production Co. STK 023N 091W 15 NW1/4NW1/4 10 P6093W 07/16/1970 Complete BP America Production Co. DOM; STK 023N 091W 33 NE1/4SW1/4 10 

P7823W 12/15/1970 Complete BP America Production Co. STK 023N 092W 2 SE1/4SW1/4 6 1,

P48078W 05/14/1979 Incomplete BP America Production Co. MIS; MON 023N 092W 5 SE1/4SE1/4 0 P48079W 05/14/1979 Incomplete BP America Production Co. MIS; MON 023N 092W 6 NE1/4NW1/4 0 

P189970W 03/27/2009 Incomplete BP America Production Co. STK 023N 092W 19 NW1/4SW1/4 25 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P14957P 09/25/1954 Complete BP America Production Co. STK 023N 092W 25 NE1/4NE1/4 25 

P14958P 12/29/1959 Complete BP America Production Co. STK 023N 092W 31 NE1/4SW1/4 25 

P14959P 08/28/1957 Complete BP America Production Co. STK 023N 093W 3 NE1/4SE1/4 25 

P2170P 03/16/1968 Complete BP America Production Co. STK 023N 093W 16 SE1/4SW1/4 25 P7824W 12/15/1970 Complete BP America Production Co. STK 023N 093W 24 NE1/4SW1/4 5 1,P59662W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NW1/4SE1/4 0 

P59663W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NW1/4SE1/4 0 

P59667W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NW1/4SE1/4 0 

P59668W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NE1/4SE1/4 0 

P59669W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NE1/4SE1/4 0 P59670W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NE1/4SE1/4 0 P59673W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NE1/4SE1/4 0 

P59679W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 NW1/4SE1/4 0 

P59682W 11/10/1981 Complete BP America Production Co. MON 023N 094W 3 NW1/4SE1/4 0 

P59683W 11/10/1981 -- BP America Production Co. MON 023N 094W 3 SW1/4SE1/4 0 

P59664W 11/10/1981 -- BP America Production Co. MON 023N 094W 10 SE1/4NE1/4 0 

P59665W 11/10/1981 -- BP America Production Co. MON 023N 094W 10 SE1/4NE1/4 0 P59666W 11/10/1981 -- BP America Production Co. MON 023N 094W 10 SE1/4NE1/4 0 P59677W 11/10/1981 -- BP America Production Co. MON 023N 094W 10 NW1/4NE1/4 0 

P59678W 11/10/1981 -- BP America Production Co. MON 023N 094W 10 NW1/4NE1/4 0 P66216W 01/09/1984 Complete BP America Production Co. MON 023N 094W 10 SE1/4SW1/4 0 

P165873W 03/25/2005 -- BP America Production Co. MIS 023N 094W 13 NW1/4NW1/4 40 

P6388P 12/31/1941 Complete BP America Production Co. STK 023N 094W 13 NW1/4NW1/4 20 P74971W 06/19/1987 -- BP America Production Co. MON 023N 094W 14 SW1/4SW1/4 0 

P7825W 12/15/1970 Complete BP America Production Co. STK 023N 094W 14 SE1/4SE1/4 8 

P158018W 04/13/2004 Complete BP America Production Co. STK 023N 094W 15 SE1/4SW1/4 7 

P6387P 12/31/1940 Complete BP America Production Co. STK 023N 094W 19 NW1/4NW1/4 12 P159305W 06/01/2004 Complete BP America Production Co. STK 023N 094W 28 SE1/4SW1/4 15 P158271W 04/23/2004 Complete BP America Production Co. STK 023N 094W 29 NE1/4SW1/4 25 

P157885W 02/02/2004 Complete BP America Production Co. STK 023N 094W 31 SE1/4SW1/4 14 P147784W 10/28/2002 -- BP America Production Co. MIS 023N 094W 35 SW1/4SW1/4 50 1,P157884W 02/02/2004 Complete BP America Production Co. STK 023N 094W 35 SW1/4NE1/4 14 

P169652W 08/02/2005 -- BP America Production Co. MIS 023N 095W 14 NW1/4SE1/4 100 P38301W 06/09/1977 Complete BP America Production Co. DOM; STK 023N 095W 25 SW1/4SW1/4 15 

P31006W 09/10/1975 Complete BP America Production Co. DOM; STK 023N 095W 29 SE1/4SW1/4 10 

P153997W 09/05/2003 -- BP America Production Co. STK 023N 095W 31 NW1/4SW1/4 25 

P153287W 08/21/2003 -- BP America Production Co. MIS 023N 095W 33 SW1/4SW1/4 90 

P156171W 05/06/2003 Complete WILLIAM H. & SALLY JOLLEY STK 023N 096W 1 SW1/4NW1/4 20 

P161187W 08/04/2004 -- Bureau of Land Management MIS 023N 096W 2 SE1/4SW1/4 200 

P155774W 05/06/2003 Complete WILLIAM H. & SALLY JOLLEY STK 023N 096W 5 NW1/4SE1/4 15 

F-52 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P153993W 09/05/2003 Complete USDI BLM STK 023N 096W 13 NW1/4SE1/4 6 

P153996W 09/05/2003 Complete Statton Sheep Co. STK 023N 096W 17 SE1/4NW1/4 14 P155771W 04/30/2003 Complete WILLIAM OR SALLY JOLLY STK 023N 096W 17 SE1/4NW1/4 25 

P155770W 04/30/2003 Complete WILLIAM H. OR SALLY K. JOLLY STK 023N 096W 18 SE1/4NW1/4 20 P156170W 04/30/2003 Complete WILLIAM H. OR SALLY K. JOLLY STK 023N 096W 21 SE1/4NW1/4 20 P35720W 12/07/1976 Complete USDI BLM STK 023N 096W 25 NW1/4NW1/4 25 1,

P105976W 05/29/1997 -- THERESA F/WILLIAM M THOMPSON DOM 023N 096W 33 SW1/4SW1/4 25 

P189475W 12/29/2008 Incomplete MAEVE AND LLIAM FITZGERALD DOM 023N 096W 33 SW1/4SW1/4 25 P153992W 09/05/2003 -- Statton Sheep Co. STK 023N 096W 34 SW1/4SW1/4 25 

P156174W 05/06/2003 Complete WILLIAM H. & SALLY JOLLEY STK 023N 097W 11 NW1/4NE1/4 20 

P55107W 12/24/1980 Complete -- STK 023N 097W 13 SE1/4SE1/4 20 P177239W 09/11/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 16 SW1/4SW1/4 25 

P177240W 09/11/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 16 SW1/4NW1/4 25 

P190519W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 16 SW1/4NE1/4 25 P190520W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 16 SW1/4SW1/4 25 

P194471W 11/23/2010 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 16 SW1/4NW1/4 25 

P175678W 07/13/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4NE1/4 25 

P175679W 07/13/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4SE1/4 25 

P175681W 07/13/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4SW1/4 25 

P175682W 07/13/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4NW1/4 25 

P190537W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4NW1/4 25 

P190538W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4SW1/4 25 

P190540W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4SE1/4 25 

P190541W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 26 SW1/4NE1/4 25 P174818W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4NE1/4 25 

P174819W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4NW1/4 25 

P174833W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4SE1/4 25 

P174834W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4SW1/4 25 

P176195W 07/27/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 35 SW1/4SW1/4 25 

P176196W 07/27/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 35 SW1/4NE1/4 25 

P190515W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4NE1/4 25 P190516W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4NW1/4 25 

P190517W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4SE1/4 25 

P190518W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 35 NE1/4SW1/4 25 P190544W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 35 SW1/4SW1/4 25 

P174815W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 NE1/4NW1/4 25 

P174816W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 NE1/4SE1/4 25 

P174817W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 NE1/4SW1/4 25 

P174820W 05/25/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 NE1/4NE1/4 25 

P175560W 06/27/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 SW1/4SE1/4 25 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P175561W 06/27/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 SW1/4SW1/4 25 

P175563W 06/27/2006 -- Pinnacle Gas Resources, Inc. CBM 023N 097W 36 SW1/4NE1/4 25 

P190542W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 36 SW1/4SW1/4 25 

P190543W 03/09/2009 Incomplete Pinnacle Gas Resources, Inc. CBM 023N 097W 36 SW1/4SE1/4 25 

P189971W 03/27/2009 Incomplete WYOMING GAME AND FISH COMMISSION STK 024N 091W 31 NE1/4SW1/4 25 

P25189P 12/13/1973 Complete -- STK 024N 091W 31 NW1/4NW1/4 25 P14956P 08/31/1957 Complete -- STK 024N 092W 33 NE1/4SE1/4 25 

P48075W 05/14/1979 Incomplete Kennecott Uranium Co. MIS; MON 024N 093W 32 NW1/4NW1/4 0 

P48076W 05/14/1979 Incomplete Kennecott Uranium Co. MIS; MON 024N 093W 32 SE1/4SE1/4 0 

P48080W 05/14/1979 Incomplete Kennecott Uranium Co. MIS; MON 024N 093W 33 SE1/4SE1/4 0 

P48074W 05/14/1979 Incomplete Kennecott Uranium Co. MIS; MON 024N 093W 35 NW1/4SW1/4 0 

P48388W 05/31/1979 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P48389W 05/31/1979 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P48390W 05/31/1979 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P48391W 05/31/1979 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P48392W 05/31/1979 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P56563W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56565W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56566W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4NW1/4 0 

P56568W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P56569W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NE1/4SW1/4 0 

P56570W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 SE1/4NW1/4 0 

P56573W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56574W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P56575W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NE1/4SW1/4 0 

P56576W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56577W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NE1/4SW1/4 0 

P56578W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56579W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NE1/4SW1/4 0 

P56580W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56581W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 SW1/4NW1/4 0 

P56582W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4SW1/4 0 

P56583W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NE1/4SW1/4 0 

P58688W 10/01/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4NW1/4 0 

P58690W 10/01/1981 -- Kennecott Uranium Co. MON 024N 094W 1 NW1/4NW1/4 0 

P56553W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 NE1/4NW1/4 0 

P56554W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 NE1/4NW1/4 0 

P56555W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 NE1/4NW1/4 0 

P56556W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 SE1/4SW1/4 0 

P56557W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 SE1/4SW1/4 0 

F-54 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P56558W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 SE1/4SW1/4 0 

P56559W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 NW1/4NW1/4 0 

P56560W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 SW1/4NE1/4 0 P56561W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 SW1/4NE1/4 0 P56564W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 2 SE1/4NE1/4 0 

P58691W 10/01/1981 -- Kennecott Uranium Co. MON 024N 094W 2 NE1/4SE1/4 0 

P56562W 02/13/1981 -- Kennecott Uranium Co. MON 024N 094W 3 SE1/4NE1/4 0 

P58689W 10/01/1981 -- Kennecott Uranium Co. MON 024N 094W 12 NE1/4NW1/4 0 

P66215W 01/09/1984 Complete Kennecott Uranium Co. MON 024N 094W 16 NW1/4NW1/4 0 

P7826W 12/15/1970 Complete -- STK 024N 094W 17 NE1/4SE1/4 1 1,0

P7551W 12/21/1970 Complete Kennecott Uranium Co. STK 024N 094W 21 NW1/4NE1/4 10 

P189665W 02/17/2009 Complete STRATTON SHEEP CO. STK 024N 094W 22 NW1/4SE1/4 25 

P61326W 06/30/1982 Complete Kennecott Uranium Co. MON 024N 094W 25 NE1/4NW1/4 0 

P183115W 08/22/2007 -- USDI BLM MIS 024N 094W 27 SW1/4SW1/4 300 

P178342W 10/17/2006 -- USDI BLM MIS 024N 094W 30 NE1/4SW1/4 120 

P9742W 07/15/1971 Fully Adjudicated Kennecott Uranium Co. IND; STK 024N 094W 34 NE1/4NE1/4 25 CR UW01/185 07/15/1971 Fully Adjudicated Green Mountain Mining Venture IND; STK 024N 094W 34 NE1/4NE1/4 25 

P155768W 04/30/2003 Complete WILLIAM H. OR SALLY K. JOLLY STK 024N 096W 8 NW1/4SE1/4 20 

P55109W 12/24/1980 Complete -- STK 024N 096W 13 SE1/4SE1/4 5 

P55110W 12/24/1980 Complete -- STK 024N 096W 18 SW1/4NE1/4 10 P155772W 04/30/2003 Complete WILLIAM H. OR SALLY K. JOLLY STK 024N 096W 24 SW1/4NE1/4 20 

P155915W 01/13/2004 -- Statton Sheep Co. STK 024N 096W 24 NW1/4SE1/4 25 

P189576W 01/26/2009 Incomplete STRATTON SHEEP CO. STK 024N 096W 24 NW1/4SE1/4 25 

P160524W 07/15/2004 Complete USDI BLM MIS 024N 096W 28 NE1/4NW1/4 120 

P186994W 04/22/2008 Incomplete GMT EXPLORATION CO., LLC MIS 024N 096W 28 NE1/4NW1/4 120 

P127205W 07/20/2000 Complete USDI BLM STK 024N 096W 35 SE1/4SW1/4 25 

P10695P 07/01/1948 Complete -- STK 024N 097W 17 NE1/4NE1/4 17 P127204W 07/20/2000 -- USDI BLM STK 024N 097W 22 NW1/4SW1/4 25 

P152043W 06/09/2003 Complete TOM BROWN, INC. MIS 024N 097W 26 NE1/4SW1/4 50 

P156175W 05/06/2003 Complete WILLIAM AND SALLY JOLLEY MIS 024N 097W 26 NE1/4SW1/4 70 

P172598W 12/30/2005 -- WILLIAM H. & SALLY JOLLEY STK 024N 097W 29 NW1/4NE1/4 25 P155773W 05/06/2003 Complete WILLIAM H. & SALLY JOLLEY DOM; STK 024N 097W 35 SE1/4SE1/4 20 

P36618W 03/21/1977 Complete P H Livestock Co. STK 024N 097W 35 SE1/4SE1/4 20 

P191915W 12/01/2009 Complete ENCANA OIL & GAS (USA) INC MIS 024N 097W 36 SW1/4SW1/4 110 

P183116W 08/22/2007 Complete J-W OPERATING COMPANY MIS 025N 094W 31 NW1/4SE1/4 200 

P191570W 08/27/2009 Complete J-W OPERATING COMPANY MIS 025N 094W 31 NW1/4SE1/4 0 P155775W 05/06/2003 Complete WILLIAM AND SALLY JOLLEY STK 025N 095W 4 NW1/4NE1/4 25 

P10293P 12/31/1930 Complete Curtis Rochelle DOM; STK 025N 096W 3 SE1/4SE1/4 10 P155769W 04/30/2003 Complete WILLIAM H. OR SALLY K. JOLLY STK 025N 096W 22 NW1/4SW1/4 20 

P10294P 12/31/1931 Complete Curtis Rochelle DOM; STK 025N 096W 30 SE1/4SE1/4 10 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-12. Groundwater rights within 1 mile of the CD-C project area, continued 

WR Number Priority Date Status Company/Individual Uses Twn Rng Sec QtrQtr Total Flow Tota

P7542P 12/31/1939 Complete -- STK 025N 096W 36 SW1/4SW1/4 20 

P7954P 12/31/1939 Complete -- STK 025N 096W 36 SW1/4SW1/4 15 

Notes for non-mining-related groundwater rights within 1 mile of the CD-C project area (search conducted February 18, 2011): Water rights were searched to the nearest quarter-quarter of each section listed above. Any part of a quarter-quarter that lies within one miles of the CD-C 

A double dash (--) indicates no information available. Record suffixes are denoted as follows: "P" Stock and domestic use wells completed prior to May 24, 1969 and registered with the State Engineer's Office prior to December 31,1972. '"W" Permits are for wells with a priority date for the date of filing with the State Engineer Use Codes CBM Coal Bed Methane DOM Domestic IND Industrial IRR Irrigation MIS Miscellaneous MON Monitoring MUN Municipal STK Stock TST Test Well Separate water rights with a status code of ABA, A&C, AME, CAN, ELI, EXP, REJ, or TRA were eliminated from the search area listing provided above (i

the mining companies), as none of these use codes represent a valid current right. Status Codes Fully Adjudicated: Well has been drilled and inspected, and a certificate of appropriation issued Complete: A notice of completion off the well has been received Unadjudicated: Well has not yet been inspected but may have been drilled Incomplete: Notice of completion of the well has not been received Expired: The permit to appropriate groundwater has expired, generally because a notice that the well has been completed has not been receiv

specified 

F-56 Continental Divide-Creston Natural Gas Development Project D
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

 Table F-13. Groundwater quality parameters for selected aquifers associated with the CD-C project area 

From Mason and Miller (2005) From Bartos et al. 2006 P

Sweetwater Co. 

Quaternary Aquifer 

Sweetwater Co. 

Wasatch Aquifer

Sweetwater Co. 

Mesaverde Aquifer 

Sweetwater Co. 

Nugget Aquifer

Sweetwater Co. 

Madison Aquifer 

Carbon Co.

Quaternary Aquifer 

Carbon Co. 

Wasatch Aquifer 

Carbon Co.

MesaverdeAquifer 

Carbon Co. Nugget 

Aquifer

Carbon Co.

Madison Aquifer 

Sweewater Co. 

Mesaverde Aquifer

Produced Water

Sweetwater Co

No. of Samples Parameter 

18 80 30 28 17 32 11 130 15 11 221 

TDS (Median) (mg/L) 1,200 8,000 1,000 10,000 11,100 500 2,000 5,000 4,500 3,000 12,000 10

TDS (Min) (mg/L) 500 150 200 3,000 3,820 30 700 250 15,000 150 2,800 5

TDS (Max) (mg/L) 20,000 153,000 20,000 35,000 76,800 8,000 5,000 40,000 50,000 12,000 65,000 40

Selenium (Median) (μg/L) 32.91 0.72 nm7 <13 nm 3.94 0.65 0.66 nm 1.43 nm 

Selenium (Min) (μg/L) 3.81 0.32 nm <13 nm <0.54 0.45 <0.36 nm 1.43 nm Selenium (Max) (μg/L) 1331 1.62 nm <13 nm 4.54 <0.75 0.86 nm 1.43 nm 

1 Based on 7 Samples 2 Based on 8 Samples 3 Based on 1 Sample 4 Based on 3 Samples 5 Based on 4 Samples Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Table F-14. Selected water quality parameters in flowing wells and springs within and adjacent to the CD-C project area 

Flowing Well or Spring Water Quality 

Reporting Agency USGS 

Station ID

411201107413801 

411149107534401 

411936107455801 

412758107424801 

412547108030801 

412932108062401 

413741107513801 

413725108170001 

414330108125501 

415340107425501 

415110107554001 

415638108125801 

MARATHON

Location 

T14N 

R92W 

S12 

T14N 

R093W 

S08 

T16N 

R092W 

S29 

T17N 

R92W 

S12 

T17N 

R95W 

S24 

T18N 

R95W 

S33 

T19N 

R093W 

S15 

T19N 

R97W 

S13 

T20N 

R96W 

S10 

T22N 

R91W 

S08 

T22N 

R93W 

S28 

T23N 

R96W 

S25 

T18N 

R93W 

S10 

Sample period 1963 1976 1958 1958 1976 1976 1958 1958 1972 1963 1963 1976 1990 Parameter Bicarbonate 719 696 453 213 403 1,080 484 458 855 157 144 1100 302 

Calcium 34 130 120 31 25 59 450 31 0 18 190 3.6 222 

Carbon Dioxide 7.3 1.8 29 5.4 4.1 43 77 18 14 10 9.2 7 nm 

Carbonate 0 0 0 0 0 0 0 0 nm 0 0 nm 0 Chloride 340 94 10 5 19 32 13 25 18 5.8 14 54 5.2 

Fluoride 1.5 1.4 0.5 0.5 2.3 3.1 0.3 nm 1.9 0.4 0.1 5.2 0.38 

Hardness 220 820 470 140 100 270 1,800 120 0 53 570 12 1,197 Magnesium 33 120 42 15 9.8 30 170 11 0 1.9 23 0.7 154 

Nitrate 0.63 nm 0.43 0.18 nm nm 0.59 2.3 0.11 0.07 0.36 nm nm 

Nitrite + Nitrate 2.8 0.03 1.9 0.8 nm nm 2.6 10 0.5 0.3 1.6 nm nm 

Noncarbonate hardness 0 250 98 0 0 0 1,400 0 0 0 450 0 nm 

pH, SU 8.2 8.8 7.4 7.8 8.2 7.6 7 7.6 8 7.4 7.4 8.4 7.4 

TDS 3,590 7,210 736 497 2,590 3,270 2,430 1,580 777 479 1,780 1,050 1,998 

Silica 5.2 13 11 6.7 13 14 18 6.4 nm 9.2 10 11 nm Sodium + potassium nm nm 79 121 nm nm 64 510 337 nm nm nm nm 

Sodium 1,200 2,100 nm nm 820 1,000 nm nm nm 150 320 420 107 

Conductance, umhos/cm 5,200 8,000 1100 776 3,800 4,600 2,680 2,310 nm 769 2,330 1,850 2,200 

Sulfate 1,600 4,400 250 210 1,500 1,600 1,500 770 0 220 1,100 4.6 1,089 

 mg/L except as noted nm = not measured 

Source: WRDS 2007; USGS 2007 

F-58 Continental Divide-Creston Natural Gas Development Project Draft 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-1. Surface water monitoring sites within and adjacent to the CD-C project area 

Source: From U.S. Geological Survey, Scientific Investigations Report 2004-5214
 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-59 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-2. Surface water rights within and adjacent to the CD-C project area 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

F-60 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-3. Groundwater rights within and adjacent to the CD-C project area 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-61 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-4. Groundwater monitoring sites within and adjacent to the CD-C project area 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

F-62 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-5. Generalized potentiometric surface and groundwater flow direction, Wasatch Aquifer 

Source: U.S. Geological Survey, Scientific Investigations Report 2004-5214
 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-63 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-6. Generalized potentiometric surface and groundwater flow direction, Mesaverde Aquifer 

Source: U.S. Geological Survey, Scientific Investigations Report 2004-5214
 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

F-64 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-7. Generalized potentiometric surface and groundwater flow direction, Tensleep Aquifer 

Source: U.S. Geological Survey, Scientific Investigations Report 2004-5214
 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 F-65 
APPENDIX F—WATER RESOURCES SUPPORTING DATA 

Map F-8. Generalized potentiometric surface and groundwater flow direction, Madison Aquifer 

Source: U.S. Geological Survey, Scientific Investigations Report 2004-5214
 

No warranty is made by the BLM for use of the data for purposes not intended by the BLM. 

F-66 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX G: ENERGY BY DESIGN—COOPERATIVE MITIGATION 

PLANNING FOR THE CD-C GAS FIELD 

Table of Contents 

Preface .......................................................................................................................................................... ii
 

Introduction and Background........................................................................................................................ 1
 

Methods ........................................................................................................................................................ 1
 

Results and Discussion ................................................................................................................................. 4
 

Literature Cited ............................................................................................................................................. 6
 

List of Tables 

Table G-1. CD-C Mitigation Planning Participants. ................................................................................ G-9
 

Table G-2. Biological targets selected for mitigation planning exercise and data source used to 

represent each target............................................................................................................ G-10
 

Table G-3. Goals for each of the biological targets by scenario ............................................................G-11
 

Table G-3. Goals for each of the biological targets by scenario ............................................................G-12

 List of Maps 

Map G-1. Biological targets with regional importance on the CD-C field ..........................................G-13
 

Map G-2. Well spacing designations on the CD-C Field and sites selected to offset impacts 

associated with development scenario 1 ..............................................................................G-14
 

Map G-3. Sites selected outside the project area to offset impacts associated with scenario 2 ...........G-15
 

Map G-4. CD-C offset site mitigation analysis, mammals..................................................................G-16
 

Map G-5. CD-C offset site mitigation analysis, ungulates ..................................................................G-17
 

Map G-6. CD-C offset site mitigation analysis, amphibians...............................................................G-18
 

Map G-7. CD-C offset site mitigation analysis, birds .......................................................................... G-19
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-i 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Preface 

Energy by Design presents a method for determining the potential for mitigation of impacts to wildlife 

that may be utilized as a result of the Continental Divide-Creston (CD-C) natural gas project. BP America 

Production Company (BP), one of the principal operators in the CD-C project area, invited The Nature 

Conservancy to design a structured framework that would evaluate the potential for conflict mitigation 

between natural gas development and wildlife and wildlife habitat. First, the framework would identify 

areas that are considered to have high wildlife values within the regional landscape and should provide 

the most effective mitigation opportunities. Second, opportunities for mitigating unavoidable impacts 

between natural gas development and identified wildlife values would be evaluated. 

The framework and potential mitigation opportunities described in Energy by Design do not have a direct 

association with the Proposed Action or any of the alternatives. This appendix and associated mitigation 

opportunities have been included in the Draft CD-C EIS for informational purposes only. This 

information may be utilized if the BLM’s final decisions on the CD-C EIS were to include the use of offsite mitigation for impacts on wildlife and wildlife habitat. 

G-ii Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Introduction and Background 

In many cases the environmental mitigation process for development projects is ad hoc, opaque, and 

insufficient, failing to deliver effective outcomes for biodiversity conservation (McKenney and Kiesecker 

2009). Mitigation planning too often reflects a reactive, piecemeal approach, focused on site-level impacts 

of the next proposed project. Here we seek to balance the needs of planned developments with those of 

biodiversity conservation. The aim is to bring greater efficiencies to development planning and impact 

mitigation, and more effective conservation outcomes. We seek to improve implementation of the 

“mitigation hierarchy” at each stage—avoid, minimize/restore, and offset—in a way that is transparent 

and transferable to industry and regulators, and complementary to the environmental assessment 

(Kiesecker et al. 2010a). By evaluating threats and impacts at regional and site levels, in a proactive 

fashion, mitigation planning can steer development projects away from conservation priorities and ensure 

mitigation provides a higher return for conservation. We generate this up-front planning information by 

harnessing decades of conservation planning experience, extensive ecological data, and advanced 

computer-modeling tools, and applying them to assess onsite conservation values as well as to locate 

compensatory mitigation opportunities. 

Mitigation frameworks often ask developers if they have followed the mitigation hierarchy (Council on 

Environmental Quality 2000) of seeking to avoid, minimize, and restore biodiversity onsite before 

considering an offset for the residual impacts. However, no quantitative guidelines exist to guide this 

decision-making process. Landscape-level planning and associated tools provide a framework to address 

this problem. Identifying wildlife values at a landscape scale and understanding the landscape value of 

local occurrences can guide decisions regarding when impacts should be avoided or when they can be 

offset. Placing mitigation design within a landscape-level planning framework can ensure that 

development actions are consistent with conservation goals. 

Here we describe an analysis for the Continental Divide-Creston (CD-C) natural gas field that can be used 

to inform avoidance of important resources onsite within the field, as well as compensatory mitigation 

opportunities. BP America Production Company (BP), one of the principal operators on the field, 

expressed the need for a structured framework to complement the Environmental Impact Statement (EIS) 

that could be used to avoid potential conflicts between development and onsite wildlife values and 

identify opportunities to balance onsite impacts with additional conservation options to offset these 

impacts. BP invited The Nature Conservancy to design such a plan. First, we identified areas within the 

field that have high value for wildlife or other resources from a regional landscape perspective and should 

be given special consideration for avoiding impacts from development. Second, we identified 

opportunities to utilize offsets to mitigate for unavoidable impacts associated with gas development on the 

field. We sought to design an offset framework where the offsets are ecologically equivalent to the 

impacts. All methods are adapted from a previous mitigation framework in Wyoming (Kiesecker et al. 

2009, Kiesecker et al. 2010b). 

Methods 

The analysis for the CD-C development included six steps, each of which is described in more detail 

below: (1) assemble a working group, (2) identify representative biological targets, (3) gather spatial data 

for biological targets, (4) examine potential onsite development, (5) set impact goals for each biological 

target associated with the development, and (6) use the Marxan algorithm at increasing spatial extents to 

identify potential offset sites both on and off the project area. 

Study area. Our study area was the 1.1-million acre CD-C natural gas field in Southern Wyoming where 

BP proposed a project that included drilling up to 8,950 new gas wells. The CD-C natural gas field is a 

high-desert xeric shrubland ecosystem that provides critical habitat for ungulates (pronghorn, mule deer 

and moose), songbirds, and raptors, in the desert shrublands west of the Sierra Madre mountain range. 

Greater sage-grouse (Centrocercus urophasianus) populations within the field are also a concern, a 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-1 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

species recently considered by the U.S. Fish and Wildlife Service (USFWS) for the endangered species 

list and issued a “warranted, but precluded” listing. 

Assemble a working group 

A mitigation-design science working group was formed to provide guidance on selection of representative 

biological targets, designing offsets, and integrating spatial data into the site selection process. These 

participants (see Table G-1) had expertise and involvement with the biological systems that may be 

impacted by the CD-C development and included representatives from the Wyoming Game and Fish 

Department (WGFD), Bureau of Land Management (BLM), USFWS, University of Wyoming (UW), 

biological consulting firms, and the local agricultural production community. The working group helped 

to provide the most current spatial data for the biological targets, assessed the predictive models being 

developed, and offered insights into the process being developed. We sought to apply rigorous, objective 

measures of conservation value whenever possible, recognizing that a quantitative assessment would need 

to be supplemented by expert opinion. Several meetings were held with members of the working group in 

2008 and 2009. 

Compile a list of representative biological targets 

Biological diversity cannot easily be completely and directly measured. Thus practitioners are forced to 

select a set of components of biological diversity that can be measured effectively given existing 

resources, that adequately represent the range of biological phenomena in the project area, and that 

contribute the most to overall biological diversity of a project area. We addressed the selection of focal 

targets that would represent wildlife values on the CD-C field with sufficient breadth and depth by 

starting with the BLM sensitive species list for the Rawlins Field Office (http://swccd.us/images/-

M_WyoBLM_Sensitivespecies.pdf). We also consulted the Wyoming Game and Fish Department’s 

Species of Greatest Conservation Concern (http://gf.state.wy.us/wildlife/CompConvStrategy/SectionI.pdf) and The Nature Conservancy’s Wyoming Basins Ecoregional Assessment 

(Freilich et al. 2001). All biological targets from these lists with data demonstrating occurrence within the 

bounds of the CD-C field area were selected as a biological targets to be included in the mitigation 

planning. 

This process resulted in 14 species and 10 systems being selected (Table G-2). The targets included three 

rare plant species—Nelson’s milkvetch (Astragalus nelsonianus), Gibben’s beardtongue (Penstemon 

gibbensii) and Persistent sepal yellowcress (Rorippa calycina)—all of which have the majority of their 

known occurrences within the study area (Fertig and Thurston 2003). All ecological systems occurring in 

the CD-C development area were included as targets and are listed in Table G-2. The eleven selected 

wildlife species included two amphibians: the northern leopard frog (Rana pipiens) and Great Basin 

spadefoot (Spea intermontana). Amphibian breeding habitat is quite rare in the Wyoming basins 

Ecoregion (Frelitch et al. 2000), meaning that occurrences of these habitats within the development area 

are particularly important. Crucial winter range and migration corridors were included for mule deer 

(Odocoileus hemionus) and pronghorn antelope (Antilocarpa americana). Adversely affecting these 

critical components of their habitat could lead to population loss—declines have been recently recorded 

for mule deer populations in the Upper Green River Basin and mule deer have been shown to avoid oil 

and gas development (Sawyer et al. 2009). The other wildlife species included were the black-footed 

ferret (Mustela nigripes), burrowing owl (Athene cunicularia), ferruginous hawk (Buteo regalis), 

mountain plover (Charadrius montanus), pygmy rabbit (Brachylagus idahoensis), and Wyoming pocket 

gopher (Spermophilus elegans). 

Wyoming pocket gophers are known only from a small area in south-central Wyoming, and the field may 

represent a significant portion of their range (Keinath and Beauvais 2006). In general, range-wide it is 

believed that pygmy rabbit abundance is declining in most known populations (Dobler and Dixon 1990). 

G-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Information suggests that pygmy rabbit populations can decline rapidly in areas where suitable habitat is 

altered (Weiss and Vert 1984, Gahr 1993), necessitating additional consideration. Burrowing owls are a 

neotropical migrant that receives protection under the Migratory Bird Treaty Act and the Convention of 

International Trade in Endangered Species, and BLM has surface occupancy stipulations for the species 

(OMBM 1995). While the FWS recognizes the ferruginous hawk as a species of concern (USFWS 1996), 

it does not give the species any special status under the Endangered Species Act. However, the 

ferruginous hawk is considered to be declining in several areas, but there is little data available on 

magnitude of declines (Bechard 1981, Houston and Bechard 1984, Woffinden and Murphy 1989, Ure et 

al. 1991). Aquatic habitats are of critical importance for wildlife in arid environments and thus all aquatic 

ecological systems have been identified (playas and riparian wet meadows). Greater sage-grouse 

(Centrocercus urophasianus), previously widespread, have been extirpated from nearly half of their 

original range in western North America (Schroeder et al. 2004) with a range-wide population decline of 

45 – 80 percent and local declines of 17 – 92 percent (Connelly and Braun 1997, Braun 1998, Connelly et 

al. 2004). Energy development has emerged as a key issue in sage-grouse conservation, as sage-grouse 

populations appear sensitive to oil and gas development (Holloran 2005, Aldridge and Boyce 2007, 

Walker et al. 2007). 

Spatial data for biological targets 

Spatial data were used to identify biological targets occurring within the CD-C field, as well as 

occurrence of those targets beyond the field boundary where offsets might be applied. The spatial datasets 

used to represent each target onsite and offsite are detailed in Table G-2 and include point survey data, 

vegetation cover estimates, and predictive model estimates. 

In cases where survey data were sufficient for estimating occurrence patterns, we relied on these data. For 

example, for pronghorn, we utilized pronghorn migration routes from the WGFD (2006). In cases where 

survey data were insufficient to estimate occurrence patterns across the study area, we used predicted 

habitat models based on species occurrence, observation, and survey data from the Wyoming Natural 

Diversity Database (WYNDD), Hayden-Wing Associates (HWA), WGFD, and the BLM. We created 

predictive habitat models for three species (Great Basin spadefoot, northern leopard frog, and sage-grouse 

winter habitat) for which existing models were not available, using methods from Kiesecker et al. (2009). 

Offset goals for biological targets 

Our intention with this analysis was not to reinvent the EIS process, as there is an extensive literature on 

this subject (Canter 1996, Sadar et al. 1995); rather we intended to provide an approach that could 

complement the ongoing EIS. Thus, for this assessment we used a simple approach to quantify field-level 

impacts and divided the field into four separate units based on the current well-spacing designations (160-

acre spacing, 80-acre spacing, 60-acre spacing and 40-acre spacing) approved by the Wyoming Oil and 

Gas Commission (http://wogcc.state.wy.us/). Since companies must actively petition to decrease well 

spacing below 160-acre spacing, we assumed that these areas have a higher probability of development. 

We set mitigation goals on and off the project field area differently. We intersected the spatial data for 

each of the biological targets with the well-spacing category and calculated the acres (for polygons) and 

number of occurrences (for points) of each target (Map G-2, Table G-2) that would need to be mitigated 

within these areas. 

We examined two possible mitigation scenarios: 

1.	 Where development and associated impacts would be concentrated with the areas designated as 40- 

and 60-acre well spacing, and set goals based on impacts to those areas. Also, we confined the areas 

that could serve as potential offset sites within the CD-C project area (Map G-2). 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-3 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

2.	 Development and associated impacts in the area designated as 80-acre spacing, and set goals based 

on impacts to those areas. Also, the analysis for potential offset sites was expanded to outside the 

CD-C project area (Maps F-2 and F-3). 

Selecting potential mitigation sites with Marxan 

We used the Marxan (version 1.8.2) site-selection algorithm (Ball and Possingham 2000) to select 

appropriate locations for potential offset sites within the onsite and offsite project areas. We developed 

criteria to ensure offsets would mitigate onsite impacts, and ran analyses based on the potential impacts 

associated with the two scenarios (40- to 60-acre spacing and 80-acre spacing). 

Marxan is a siting tool for landscape conservation analysis that explicitly incorporates spatial design 

criteria into the site-selection process. Marxan operates as a stand-alone program and utilizes an algorithm 

called “simulated annealing with iterative improvement” as a heuristic method for efficiently selecting 

regionally representative sets of areas for biodiversity conservation (Possingham et al. 2000). Marxan 

allows inputs of target occurrences represented as points or polygons in a GIS environment and allows for 

conservation goals to be stated in a variety of ways, such as percent area or numbers of point occurrences. 

The program also allows for the integration of spatial data sets representing land use pattern and 

conservation status, and enables rapid evaluation of alternative configurations or scenarios. The ultimate 

objective is to minimize the cost of the sites selected (i.e. cost = landscape integrity, conservation cost in 

dollars, size of the reserve) while still meeting objectives. 

The working group selected 100-hectare (approximately 250-acre) hexagons as the unit of analysis for 

running Marxan, because this was of sufficient spatial resolution to represent biological targets and also 

large enough to permit efficient analyses across broad landscape scales. The effectiveness of a contiguous 

set of hexagon units for defining natural variability, especially among spatially heterogeneous data sets, is 

well documented (White et al. 1992). Each hexagon was populated by summing the area of suitable 

habitat for the targeted community or species. In addition to the biological information used to select 

potential offset sites, we incorporated a series of additional rules. First we guided site selection to areas of 

high biological integrity (as per Copeland et al. 2007). This is equivalent to the “cost” function utilized by 

Marxan (Ball and Possingham 2000). 

Results and Discussion 

These results complement the planning and analysis work conducted as part of the CD-C EIS, provides an 

assessment of biological values that are important at a regional scale, and identifies areas where 

conservation projects targeted at impacted species may provide a way to offset impacts associated with 

development. 

Mapping Sensitive Features 

Our maps and data of sensitive features (Map G-1) could be used in a variety of ways to both avoid 

potential conflicts between development and key wildlife resources on the field and minimize impacts 

associated with development. For example, impacts to known rare plant occurrences (Nelson milkvetch, 

Gibbens’ penstemon and persistent sepal yellowcress) should be avoided given their limited distributions 

and occurrence patterns. Furthermore, predictive habitat species models could be used to guide surveys 

prior to development. Impacts to rare and/or sensitive animal species (Wyoming pocket gopher, 

ferruginous hawk, pygmy rabbit, sage-grouse and burrowing owl) should be avoided whenever possible. 

For sage-grouse this should include both breeding (= leks) and wintering habitat. Aquatic targets (playas, 

wet meadows, and amphibians, including northern leopard frog and Great Basin spadefoot toad) should 

also be given special consideration and impacts to any riparian or wetland habitats should be avoided. 

G-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Onsite and Offsite Mitigation Areas 

Mitigation sites could be used in a number of ways to compensate for impacts associated with 

development. A simple approach may be for BLM to establish a surface disturbance (or activity) 

threshold on a section-by-section basis (or some other spatial unit) and if development exceeds these 

disturbance caps it would trigger the need to offset the wildlife values within that section. Alternatively, 

monitoring plots both within development areas and outside development areas could be established for 

key wildlife targets. Monitoring that reveals departures (declining trends in populations or habitat quality 

indices) between development and non-development areas could trigger the need for offsets and could be 

directed at declining species. For this reason we have included an assessment of offset sites and the 

species/systems they may benefit. 

It is important to note that our site-selection exercise did not account for future oil and gas development 

potential. Prior to establishing these sites for actual mitigation offsets, the development potential should 

be carefully evaluated and incorporated into the decision-making process. 

If offsets are used, a number of criteria will need to be addressed to ensure offsets provide the needed 

benefit. Critical to their usage will be the demonstration of additional conservations benefits (Kiesecker et 

al. 2009a) that accrue to impacted wildlife species and systems. Areas selected will only be valuable as 

offsets if opportunities exist to either restore (i.e. improve conditions for target species) habitat or abate 

future threats (i.e. prevent invasive weed establishment, conservation easements) to habitat in a manner 

that improves the condition for target species. Reaching no net loss from impacts associated with 

development will come from onsite actions that minimize impacts or restore habitat, combined with 

offsite actions that provide additional benefits. As on-the ground projects are considered, a finer currency 

that incorporates the size of the impact and offset, as well as values associated with ecological function, 

quality, and integrity will need to be established (Kiesecker et al. 2009a). For the sagebrush ecosystem, 

several site assessment tools are available for use (i.e., USFWS 1980, habitat evaluation procedures; 

USNRCS 1997, ecological site descriptions; Parkes et al. 2003, habitat hectares approach). 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-5 
 

 

APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Literature Cited 

Aldridge, C. L., and M. S. Boyce. 2007. Linking occurrence and fitness to persistence: habitat-based 

approach for endangered Greater Sage-Grouse. Ecological Applications 17:508-526. 

Ball IR, Possingham HP. 2000. MARXAN (V1.8.2): Reserve Design Using Spatially Explicit Annealing, 

a Manual 

Bechard, M.J. 1981. Historical nest records for the ferruginous hawk in Manitoba. Canadian FieldNaturalist 95:467-469. 

Berger J, Cain SL, Berger KM. 2006. Connecting the dots: an invariant migration corridor links the 

Holocene to the present. Biology Letters 10: 1-4 

Braun, C. E. 1998. Sage grouse declines in western North America: what are the problems? 

Bureau of Land Management. 2002. BLM Wyoming Sensitive Species Policy and List. September 20, 

2002. http://swccd.us/images/M_WyoBLM_Sensitivespecies.pdf 

Canter L. 1996 Environmental Impact Assessment, Second Edition, McGraw Hill, New York, USA. 

Connelly, J. W. and C. E. Braun. 1997. Long-term changes in Sage-Grouse Centrocercus urophasianus 

populations in western North America. Wildlife Biology 3:229-234. 

Connelly, J. W., S. T. Knick, M. A. Schroeder, and S. J. Stiver. 2004. Conservation assessment of greater 

sage-grouse and sagebrush habitats. Western Association of Fish and Wildlife Agencies. 

Cheyenne, Wyoming, USA. 

Copeland H, Ward J, Kiesecker JM. 2007. Threat, cost, and biological value: Prioritizing conservation 

within Wyoming ecoregions Journal of Conservation Planning 3(2007): 1-16. 

Council on Environmental Quality. 2000. Protection of the Environment (under the National Environment 

Policy Act) (40 CFR 1500-1517). 

Davidson, A., Aycrigg, J., Grossmann, E., Kagan, J., Lennartz, S., McDonough, S., Miewald, T., 

Ohmann, J., Radel, A., Sajwaj, T., & Tobalske, C. (2009). Digital Land Cover Map for the 

Northwestern United States. In. Northwest Gap Analysis Project, USGS GAP Analysis Program, 

Moscow, Idaho. 

Dobler, F.C. and K.R. Dixon. 1990. The pygmy rabbit Brachylagus idahoensis. In Rabbits, hares and 

pikas: Status survey and conservation action plan. J.A. Chapman and J.E.C. Flux, eds., IUCN, 

Gland, Switzerland, p.111-115. 

Fertig W, Thurston R. 2003. Modeling the potential distribution of BLM sensitive and USFWS 

threatened and endangered plant species in Wyoming. Final Report to the Bureau of Land 

Management, Agreement No. KAA010012, Task Order No. TO-6. Wyoming Natural 

Diversity Database, University of Wyoming, Laramie, WY. 

Freilich J, Budd B, Kohley T, Hayden B. 2001. The Wyoming basins ecoregional plan. TNC Wyoming 

Field Office, Lander, Wyoming. 

Gahr, M.L. 1993. Natural history, burrow habitat and use, and home range of the pygmy rabbit 

(Brachylagus idahoensis) of Sagebrush Flat, Washington. M.S. thesis. University of Washington, 

Seattle, Washington. 

Holloran, M. J. 2005. Greater Sage-Grouse (Centrocercus urophasianus) population response to gas field 

development in western Wyoming. Ph.D. dissertation, University of Wyoming, Laramie, WY. 

G-6 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Houston, C.S. and M.J. Bechard. 1984. Decline of the ferruginous hawk in Saskatchewan. American 

Birds 38:166-170. 

Keinath, D.A. and G.P. Beauvais. 2006. Wyoming Pocket Gopher (Thomomys clusius): a technical 

conservation assessment. [Online]. USDA Forest Service, Rocky Mountain Region. Available: 

http://www.fs.fed.us/r2/projects/scp/assessments/wyomingpocketgopher.pdf. 

Kiesecker, J., H. Copeland, B. McKenney, A. Pocewicz, and K. Doherty, editors. 2010a. Energy 

development and wildlife conservation in Western North America. Island Press. 

McKenney, B. 2005. Environmental Offset Policies, Principles, and Methods: A Review of Selected 

Legislative Frameworks. 85 pages. Biodiversity Neutral Initiative, Amherst, NH, USA. 

Office of Migratory Bird Management. 1995. Migratory nongame birds of management concern in the 

United States: the 1995 list. U.S. Fish and Wildlife Service, Washington, D.C. 

Parkes, D., G. Newell, and D. Cheal. 2003. Assessing the quality of native vegetation: The ‘habitat 

hectares’ approach. Ecological Management & Restoration, vol. 4 supplement. February 2003. 

Possingham, H.P., I.R. Ball, and S. Andelman. 2000. Mathematical methods for identifying representative 

reserve networks. In: S. Ferson and M. Burgman (eds) Quantitative methods for conservation 

biology. Springer-Verlag, New York, pp. 291-305. 

Sadar, M.H., D.R. Cressman, and D.C. Damman. 1995. Cumulative effects assessment: the development 

of practical frameworks. Impact Assessment 13:4 

Sawyer, H., M. J. Kauffman, and R. M. Nielson. 2009. Influence of well pad activity on the winter habitat 

selection patterns of mule deer. Journal of Wildlife Management 73:1052-1061. 

Schroeder, M. A., et al. 2004. Distribution of sage-grouse in North America. Condor 106:363-376. 

Shill S. and G. Raber. 2008. Protected Area Tools (PAT) for ArcGIS 9.2 ver 2.0. The Nature 

Conservancy. 75 p. 

ten Kate, K., J. Bishop, and R. Bayon. 2004. Biodiversity offsets: Views, experience, and the business 

case. IUCN, Gland, Switzerland and Cambridge, UK, and Insight Investment, London, UK. 

USDI Fish and Wildlife Service. 1996. Threatened wildlife and plants: review of plant and animal 

taxa that are candidates for listing as endangered or threatened species - notice of review. 

Federal Register 61. 

United States Forest Service 2006. Landfire Existing Vegetation Height (EVH), Existing Vegetation Type 

(EVT) and Existing Vegetation Cover (EVC) downloaded from www.landfire.gov, Missoula, 

MT. 

Ure, J., P. Briggs and S.W. Hoffman. 1991. A petition to list as endangered the ferruginous hawk (Buteo 

regalis), as provided by the Endangered Species Act of 1973, as amended in 1982. Letter to 

Director. USDI Fish and Wildlife Service. Washington, DC, USA. 

Walker, B. L., D. E. Naugle, and K. E. Doherty. 2007. Greater Sage-Grouse population response to 

energy development and habitat loss. Journal of Wildlife Management 71:2644-2654. 

Weiss, N.T. and B.J. Verts. 1984. Habitat and distribution of pygmy rabbits (Sylvilagus idahoensis) in 

Oregon. Great Basin Naturalist 44:563-571. 

White, D., A.J Kimerling, and W.S. Overton. 1992. Cartographic and geometric components of a global 

sampling design for environmental monitoring. Cartography and Geographic Information 

Systems 19: 5-22. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-7 
APPENDIX G—COOPERATIVE MITIGATION PLANNING 

Woffinden, N.D. and J.R. Murphy. 1983. Ferruginous hawk nest site selection. Journal of Wildlife 

Management 47:216-219. 

Wyoming Game and Fish Department. 2008. Annual Big Game Herd Unit Report. Jackson/Pinedale 

Region. Wyoming Game and Fish Department, Cheyenne, WY. 

Wyoming Game and Fish Department. 2005. A Comprehensive Wildlife Conservation Strategy for 

Wyoming. Cheyenne, WY. http://gf.state.wy.us/wildlife/CompConvStrategy/SectionI.pdf 

G-8 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Table G-1. CD-C Mitigation Planning Participants. 

Name Email Organization 

Michael A. Smith pearl@uwyo.edu University of Wyoming 

Rhen Etzelmiller Rhen_Etzelmiller@blm.gov Bureau of Land Management 

Debbie Johnson Debbie_Johnson@blm.gov; Bureau of Land Management 

David Simons David_Simons@blm.gov; Bureau of Land Management 

Mary Read Mary_Read@blm.gov; Bureau of Land Management 

Eldon Allison Eldon_Allison@blm.gov; Bureau of Land Management 

Andy Warren Andy_Warren@blm.gov Bureau of Land Management 

Cheryl Newberry Cheryl_Newberry@blm.gov Bureau of Land Management 

Tim Woolley Tim.Woolley@wgf.state.wy.us Wyoming Game and Fish Department 

Greg Hiatt Greg.Hiatt@wgf.state.wy.us Wyoming Game and Fish Department 

Scott Smith Scott.Smith@wgf.state.wy.us Wyoming Game and Fish Department 

Joseph Kiesecker jkiesecker@tnc.org The Nature Conservancy 

Holly Copeland hcopeland@tnc.org The Nature Conservancy 

Amy Pocewicz apocwicz@tnc.org The Nature Conservancy 

Steve Moore smoore35@bresnan.net Gary Holsan Environmental Planning 

Douglas A. Keinath dkeinath@uwyo.edu WYNDD 

Jason Sutter jason@haydenwing.com Hayden-Wing Associates, LLC 

Dick Loper dloper@wyoming.com Consultant 

Don Schramm dschramm@wyoming.com Rock Springs Grazing Board 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-9 
APPENDIX G—COOPERATIVE MITIGATION PLANNING 

Table G-2. Biological targets selected for mitigation planning exercise and data source used to 

represent each target 

Target Name Onsite Offsite 

Basin Grassland HWA vegetation map WY Basins re-GAP vegetation map 

Black-footed ferret 

habitat 

BLM potential habitat from prairie dog town 

maps 

BLM potential habitat from prairie dog 

town maps 

Burrowing owl BLM nest data (not including historical), with 

825 ft buffer 

BLM nest data (not including historical), 

with 825 ft buffer 

Ferruginous hawk BLM natural nests, not including historical, 

with 1/4 mi (1,200 ft) buffer 

BLM natural nests, not including 

historical, with 1/4 mi (1200 ft) buffer 

Gibben's beardtongue WYNDD model (no known locations onsite) WYNDD model 

Greasewood Fans and 

Flats HWA vegetation map WY Basins re-GAP vegetation map 

Great Basin spadefoot BLM/WYNDD occurrences BLM/WYNDD occurrences 

Great Basin spadefoot 

habitat 

National Wetlands Inventory (modeled 

habitat) 

National Wetlands Inventory (modeled 

habitat) 

Juniper Woodland HWA vegetation map WY Basins re-GAP vegetation map 

Mixed Desert Shrub HWA vegetation map WY Basins re-GAP vegetation map 

Mountain Big 

Sagebrush-Mixed 

Mountain Shrub 

HWA vegetation map WY Basins re-GAP vegetation map 

Mountain Plover Habitat HWA model WYNDD domain model 

Mule deer crucial winter Wyoming Game and Fish Department 

(2004) 

Wyoming Game and Fish Department 

(2004) 

Mule deer migration 

corridor 

Wyoming Game and Fish Department 

(2007) 

Wyoming Game and Fish Department 

(2007) 

Nelson’s milkvetch WYNDD occurrences WYNDD occurrences 

Nelson’s milkvetch 

habitat WYNDD habitat model WYNDD habitat model 

Northern leopard frog BLM/WYNDD occurrences BLM/WYNDD occurrences 

Northern leopard frog 

habitat 

National Wetlands Inventory (modeled 

habitat) 

National Wetlands Inventory (modeled 

habitat) 

Persistent sepal 

yellowcress HWA Inventory (Lost Creek polygon) WYNDD habitat model 

Playa HWA vegetation map WY Basins re-GAP vegetation map 

Pronghorn crucial winter 

range 

Wyoming Game and Fish Department 

(2004) 

Wyoming Game and Fish Department 

(2004) 

Pronghorn migration 

corridor 

Wyoming Game and Fish Department 

(2007) 

Wyoming Game and Fish Department 

(2007) 

Pygmy rabbit BLM/WYNDD occurrences BLM/WYNDD occurrences 

Pygmy rabbit habitat WYNDD habitat model (March 2008) WYNDD habitat model (March 2008) 

Riparian-Wet Meadow HWA vegetation map WY Basins re-GAP 

Sage-grouse breeding 

areas 

BLM/WGFD lek data, with 1/4 mi (1200 ft) 

buffer 

BLM/WGFD lek data, with 1/4 mi (1200 

ft) buffer 

G-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 9, 2012 
APPENDIX G—COOPERATIVE MITIGATION PLANNING 

Table G-2. Biological targets selected for mitigation planning exercise and data source used to 

represent each target, continued 

Target Name Onsite Offsite 

Sage-grouse severe 

winter range 

HWA model (high potential) and known 

winter locations TNC habitat model (2009) 

Saltbush Fans and Flats HWA vegetation map WY Basins re-GAP vegetation map 

Vegetated Sand Dunes HWA vegetation map WY Basins re-GAP vegetation map 

Wyoming Big 

Sagebrush-Basin Big 

Sagebrush 

HWA vegetation map WY Basins re-GAP vegetation map 

Wyoming pocket gopher BLM/WYNDD occurrences BLM/WYNDD occurrences 

Wyoming pocket gopher 

habitat WYNDD habitat model (Dec 2008) WYNDD habitat model (Dec 2008) 

1 These acre estimates were used as offset goals for Scenario 1 (40- and 60-acre spacing) and Scenario 2 (80-acre spacing). 

Table G-3. Goals for each of the biological targets by scenario 

Target Name 

Highly 

Sensitive 

Conservation 

goals within 

the onsite 

project area 

(Scenario 1) 

Acres selected 

onsite by 

Marxan 

Conservation 

goals within 

the offsite 

project area 

(Scenario 2) 

Acres selected 

offsite by 

Marxan 

Basin Grassland NO 391 391 1,404 2,141 

Black-footed ferret habitat NO 30,729 23,133 23,955 12,204 

Burrowing owl YES 53 73 328 315 

Ferruginous hawk YES 1,052 1,629 6,964 7,898 

Greasewood Fans and Flats NO 9,725 16,256 42,342 17,953 

Great Basin spadefoot 

habitat YES 448 741 815 968 

Juniper Woodland NO 0 0 122 794 

Mixed Desert Shrub NO 8,368 9,586 30,970 50,761 

Mountain Big SagebrushMixed Mountain Shrub NO 1,660 4,117 11,456 11,470 

Mountain plover habitat NO 34,911 34,913 77,515 120,812 

Mule deer crucial winter YES 0 189 6,012 35,654 

Mule deer migration corridor YES 0 230 3,550 22,590 

Nelson’s milkvetch YES 0 2 0 0 

Nelson’s milkvetch habitat NO 0 9,490 15,517 2,837 

Northern leopard frog YES 0 1 1 2 

Northern leopard frog habitat YES 30 35 41 984 

Gibben's beardtongue YES 0 1 2,923 7,579 

Playa YES 3 5 25 3,914 

Pronghorn crucial winter YES 1,492 3,086 21,529 15,311 

Pronghorn migration corridor YES 0 22,245 35,494 35,521 

Pygmy rabbit YES 70 70 163 104 

Pygmy rabbit habitat NO 47,102 67,483 177,295 200,261 

Riparian-Wet Meadow YES 7 109 18 3,102 

Persistent sepal yellowcress YES 0 10 0 14,368 

Sage-grouse breeding areas YES 453 463 1,882 2,519 

Sage-grouse severe winter 

locations YES 2 13 0 0 

Sage-grouse winter habitat NO 10,536 13,176 38,766 34,105 

Saltbush Fans and Flats NO 17,196 17,189 27,015 27,016 

Vegetated Sand Dunes YES 0 71 35 10,923 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 9, 2012 G-11 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Table G-3. Goals for each of the biological targets by scenario, continued 

Target Name 

Highly 

Sensitive 

Conservation 

goals within 

the onsite 

project area 

(Scenario 1) 

Acres selected 

onsite by 

Marxan 

Conservation 

goals within 

the offsite 

project area 

(Scenario 2) 

Acres selected 

offsite by 

Marxan 

Wyoming Big SagebrushBasin Big Sagebrush NO 19,562 23,014 79,127 97,228 

Wyoming pocket gopher YES 0 1 5 1 

Wyoming pocket gopher 

habitat NO 43,654 43,658 100,754 100,952 

G-12 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 9, 2012 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-1. Biological targets with regional importance on the CD-C field. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-13 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-2. Well spacing designations on the CD-C Field and sites selected to offset impacts associated 

with development scenario 1 (wells concentrated with areas designated as 40- and 60-acre well spacing). 

G-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-3. Sites selected outside the project area to offset impacts associated with scenario 2

(wells concentrated with areas designated as 80-acre well spacing). 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-15 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-4. CD-C offset site mitigation analysis, mammals 

G-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-5. CD-C offset site mitigation analysis, ungulates 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-17 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-6. CD-C offset site mitigation analysis, amphibians 

G-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX G—COOPERATIVE MITIGATION PLANNING
 

Map G-7. CD-C offset site mitigation analysis, birds 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 G-19 
APPENDIX H: OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C 

PROJECT AREA 

Common Name: Birds Scientific Name Occurrence Potential1 

Snow Goose Chen caerulescens O 

Ross’s Goose Chen rossii O 

Canada Goose Branta canadensis B 

Trumpeter Swan Cygnus buccinator O 

Tundra Swan Cygnus columbianus O 

Wood Duck Aix sponsa O 

Gadwall Anas strepera B 

American Wigeon Anas americana B 

Mallard Anas platyrhynchos B 

Blue-winged Teal Anas discors b 

Cinnamon Teal Anas cyanoptera B 

Northern Shoveler Anas clypeata B 

Northern Pintail Anas acuta B 

Green-winged Teal Anas crecca B 

Canvasback Aythya valisineria O 

Redhead Aythya americana B 

Ring-necked Duck Aythya collaris O 

Greater Scaup Aythya marila O 

Lesser Scaup Aythya affinis B 

Surf Scoter Melanitta perspicillata O 

White-winged Scoter Melanitta fusca O 

Long-tailed Duck Clangula hyemalis O 

Bufflehead Bucephala albeola O 

Common Goldeneye Bucephala clangula O 

Barrow’s Goldeneye Bucephala islandica O 

Hooded Merganser Lophodytes cucullatus O 

Common Merganser Mergus merganser b 

Red-breasted Merganser Mergus serrator O 

Ruddy Duck Oxyura jamaicensis O 

Greater Sage-Grouse Centrocercus urophasianus B 

Dusky Grouse Dendragapus obscurus B 

Columbian Sharp-tailed Grouse Tympanuchus phasianellus columbianus B 

Pacific Loon Gavia pacifica O 

Common Loon Gavia immer O 

Pied-billed Grebe Podilymbus podiceps b 

Horned Grebe Podiceps auritus O 

Red-necked Grebe Podiceps grisegena O 

Eared Grebe Podiceps nigricollis B 

Western Grebe Aechmophorus occidentalis O 

Clark's Grebe Aechmophorus clarkii O 

American White Pelican Pelecanus erythrorhynchos O 

Double-crested Cormorant Phalacrocorax auritus O 

American Bittern Botaurus lentiginosus O 

Great Blue Heron Ardea herodias B 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 H-1 
 

APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA 

Common Name: Birds Scientific Name Occurrence Potential1 

Snowy Egret Egretta thula O 

Cattle Egret Bubulcus ibis O 

Green Heron Butorides virescens O 

Black-crowned Night-Heron Nycticorax nycticorax O 

White-faced Ibis Plegadis chihi O 

Turkey Vulture Cathartes aura O 

Osprey Pandion haliaetus BLM 

Bald Eagle Haliaeetus leucocephalus O 

Northern Harrier Circus cyaneus B 

Sharp-shinned Hawk Accipiter striatus b 

Cooper’s Hawk Accipiter cooperii B 

Northern Goshawk Accipiter gentilis O 

Broad-winged Hawk Buteo platypterus O 

Swainson’s Hawk Buteo swainsoni B 

Red-tailed Hawk Buteo jamaicensis B 

Ferruginous Hawk Buteo regalis B 

Rough-legged Hawk Buteo lagopus O 

Golden Eagle Aquila chrysaetos B 

American Kestrel Falco sparverius B 

Merlin Falco columbarius O 

Peregrine Falcon Falco peregrinus O 

Prairie Falcon Falco mexicanus B 

Gyrfalcon Falco rusticolus BLM 

Virginia Rail Rallus limicola b 

Sora Porzana carolina b 

American Coot Fulica americana B 

Sandhill Crane Grus canadensis O 

Black-bellied Plover Pluvialis squatarola O 

Snowy Plover Charadrius alexandrinus O 

Semipalmated Plover Charadrius semipalmatus O 

Killdeer Charadrius vociferus B 

Mountain Plover Charadrius montanus B 

Black-necked Stilt Himantopus mexicanus O 

American Avocet Recurvirostra americana B 

Spotted Sandpiper Actitis macularius b 

Solitary Sandpiper Tringa solitaria O 

Greater Yellowlegs Tringa melanoleuca O 

Willet Tringa semipalmata B 

Lesser Yellowlegs Tringa flavipes O 

Whimbrel Numenius phaeopus O 

Long-billed Curlew Numenius americanus O 

Marbled Godwit Limosa fedoa O 

Ruddy Turnstone Arenaria interpres O 

Red Knot Calidris canutus O 

Sanderling Calidris alba O 

Semipalmated Sandpiper Calidris pusilla O 

Western Sandpiper Calidris mauri O 

H-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA
 

Common Name: Birds Scientific Name Occurrence Potential1 

Least Sandpiper Calidris minutilla O 

Baird’s Sandpiper Calidris bairdii O 

Pectoral Sandpiper Calidris melanotos O 

Dunlin Calidris alpina O 

Stilt Sandpiper Calidris himantopus O 

Buff-breasted Sandpiper Tryngites subruficollis O 

Short-billed Dowitcher Limnodromus griseus O 

Long-billed Dowitcher Limnodromus scolopaceus O 

Wilson’s Snipe Gallinago delicata b 

Wilson’s Phalarope Phalaropus tricolor B 

Red-necked Phalarope Phalaropus lobatus O 

Red Phalarope Phalaropus fulicarius O 

Franklin’s Gull Larus pipixcan O 

Bonaparte’s Gull Larus philadelphia O 

Ring-billed Gull Larus delawarensis O 

California Gull Larus californicus O 

Herring Gull Larus argentatus O 

Sabine’s Gull Xema sabini O 

Caspian Tern Hydroprogne caspia O 

Common Tern Sterna hirundo O 

Forster’s Tern Sterna forsteri O 

Black Tern Chlidonias niger O 

Rock Pigeon Columba livia B 

White-winged Dove Zenaida asiatica O 

Mourning Dove Zenaida macroura B 

Yellow-billed Cuckoo Coccyzus americanus BLM 

Black-billed Cuckoo Coccyzus erythropthalmus O 

Barn Owl Tyto alba O 

Great Horned Owl Bubo virginianus B 

Snowy Owl Bubo scandiacus O 

Burrowing Owl Athene cunicularia B 

Long-eared Owl Asio otus B 

Short-eared Owl Asio flammeus b 

Northern Pygmy Owl Glaucidium gnoma BLM 

Northern Saw-whet Owl Aegolius acadicus O 

Common Nighthawk Chordeiles minor B 

Common Poorwill Phalaenoptilus nuttallii B 

White-throated Swift Aeronautes saxatalis b 

Calliope Hummingbird Stellula calliope B 

Broad-tailed Hummingbird Selasphorus platycercus O 

Rufous Hummingbird Selasphorus rufus O 

Belted Kingfisher Ceryle alcyon B 

Lewis’s Woodpecker Melanerpes lewis O 

Red-headed Woodpecker Melanerpes erythrocephalus O 

Acorn Woodpecker Melanerpes formicivorus O 

Williamson’s Sapsucker Sphyrapicus thyroideus O 

Red-naped Sapsucker Sphyrapicus nuchalis O 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 H-3 
APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA 

Common Name: Birds Scientific Name Occurrence Potential1 

Downy Woodpecker Picoides pubescens O 

Hairy Woodpecker Picoides villosus B 

American Three-toed Woodpecker Picoides dorsalis O 

Northern Flicker Colaptes auratus B 

Olive-sided Flycatcher Contopus cooperi b 

Western Wood-Pewee Contopus sordidulus O 

Willow Flycatcher Empidonax traillii O 

Least Flycatcher Empidonax minimus b 

Hammond's Flycatcher Empidonax hammondii B 

Gray Flycatcher Empidonax wrightii b 

Dusky Flycatcher Empidonax oberholseri b 

Cordilleran Flycatcher Empidonax occidentalis B 

Say's Phoebe Sayornis saya B 

Ash-throated Flycatcher Myiarchus cinerascens b 

Western Kingbird Tyrannus verticalis O 

Eastern Kingbird Tyrannus tyrannus O 

Loggerhead Shrike Lanius ludovicianus b 

Northern Shrike Lanius excubitor O 

Plumbeous Vireo Vireo plumbeus O 

Warbling Vireo Vireo gilvus b 

Philadelphia Vireo Vireo philadelphicus b 

Red-eyed Vireo Vireo olivaceus b 

Gray Jay Perisoreus canadensis O 

Steller’s Jay Cyanocitta stelleri O 

Blue Jay Cyanocitta cristata O 

Western Scrub-Jay Aphelocoma californica b 

Pinyon Jay Gymnorhinus cyanocephalus b 

Clark’s Nutcracker Nucifraga columbiana b 

Black-billed Magpie Pica hudsonia B 

American Crow Corvus brachyrhynchos O 

Common Raven Corvus corax O 

Horned Lark Eremophila alpestris B 

Tree Swallow Tachycineta bicolor B 

Violet-green Swallow Tachycineta thalassina B 

Northern Rough-winged Swallow Stelgidopteryx serripennis b 

Bank Swallow Riparia riparia b 

Cliff Swallow Petrochelidon pyrrhonota B 

Barn Swallow Hirundo rustica B 

Black-capped Chickadee Poecile atricapillus B 

Mountain Chickadee Poecile gambeli b 

Juniper Titmouse Baeolophus ridgwayi B 

Bushtit Psaltriparus minimus b 

Red-breasted Nuthatch Sitta canadensis B 

White-breasted Nuthatch Sitta carolinensis O 

Brown Creeper Certhia americana B 

Rock Wren Salpinctes obsoletus B 

Canyon Wren Catherpes mexicanus b 

H-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA
 

Common Name: Birds Scientific Name Occurrence Potential1 

Bewick’s Wren Thryomanes bewickii B 

House Wren Troglodytes aedon B 

Marsh Wren Cistothorus palustris b 

American Dipper Cinclus mexicanus b 

Golden-crowned Kinglet Regulus satrapa O 

Ruby-crowned Kinglet Regulus calendula B 

Blue-gray Gnatcatcher Polioptila caerulea b 

Western Bluebird Sialia mexicana O 

Mountain Bluebird Sialia currucoides B 

Townsend’s Solitaire Myadestes townsendi b 

Veery Catharus fuscescens O 

Swainson’s Thrush Catharus ustulatus O 

Hermit Thrush Catharus guttatus B 

American Robin Turdus migratorius B 

Gray Catbird Dumetella carolinensis b 

Northern Mockingbird Mimus polyglottos O 

Sage Thrasher Oreoscoptes montanus B 

Brown Thrasher Toxostoma rufum O 

European Starling Sturnus vulgaris b 

American Pipit Anthus rubescens O 

Bohemian Waxwing Bombycilla garrulus O 

Cedar Waxwing Bombycilla cedrorum O 

Tennessee Warbler Vermivora peregrina O 

Orange-crowned Warbler Vermivora celata B 

Nashville Warbler Vermivora ruficapilla O 

Virginia’s Warbler Vermivora virginiae O 

Yellow Warbler Dendroica petechia b 

Yellow-rumped Warbler Dendroica coronata B 

Black-throated Gray Warbler Dendroica nigrescens b 

Townsend’s Warbler Dendroica townsendi O 

Black-and-white Warbler Mniotilta varia O 

American Redstart Setophaga ruticilla O 

Ovenbird Seiurus aurocapilla O 

Northern Waterthrush Seiurus noveboracensis O 

MacGillivray’s Warbler Oporornis tolmiei B 

Common Yellowthroat Geothlypis trichas b 

Wilson’s Warbler Wilsonia pusilla O 

Yellow-breasted Chat Icteria virens b 

Western Tanager Piranga ludoviciana b 

Green-tailed Towhee Pipilo chlorurus B 

Spotted Towhee Pipilo maculatus b 

American Tree Sparrow Spizella arborea O 

Chipping Sparrow Spizella passerina B 

Clay-colored Sparrow Spizella pallida O 

Brewer’s Sparrow Spizella breweri B 

Vesper Sparrow Pooecetes gramineus B 

Lark Sparrow Chondestes grammacus b 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 H-5 
APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA 

Common Name: Birds Scientific Name Occurrence Potential1 

Black-throated Sparrow Amphispiza bilineata O 

Sage Sparrow Amphispiza belli B 

Lark Bunting Calamospiza melanocorys B 

Savannah Sparrow Passerculus sandwichensis b 

Baird’s Sparrow Ammodramus bairdii BLM 

Fox Sparrow Passerella iliaca O 

Song Sparrow Melospiza melodia b 

Lincoln’s Sparrow Melospiza lincolnii O 

Swamp Sparrow Melospiza georgiana O 

White-crowned Sparrow Zonotrichia leucophrys b 

Dark-eyed Junco Junco hyemalis B 

McCown’s Longspur Calcarius mccownii O 

Chestnut-collared Longspur Calcarius ornatus O 

Snow Bunting Plectrophenax nivalis O 

Rose-breasted Grosbeak Pheucticus ludovicianus O 

Black-headed Grosbeak Pheucticus melanocephalus B 

Blue Grosbeak Passerina caerulea O 

Lazuli Bunting Passerina amoena O 

Indigo Bunting Passerina cyanea O 

Bobolink Dolichonyx oryzivorus O 

Red-winged Blackbird Agelaius phoeniceus B 

Western Meadowlark Sturnella neglecta B 

Yellow-headed Blackbird Xanthocephalus xanthocephalus B 

Brewer’s Blackbird Euphagus cyanocephalus B 

Common Grackle Quiscalus quiscula O 

Brown-headed Cowbird Molothrus ater B 

Bullock's Oriole Icterus bullockii O 

Scott’s Oriole Icterus parisorum b 

Gray-crowned Rosy-Finch Leucosticte tephrocotis O 

Black Rosy-Finch Leucosticte atrata O 

Brown-capped Rosy-Finch Leucosticte australis O 

Pine Grosbeak Pinicola enucleator O 

Cassin’s Finch Carpodacus cassinii B 

House Finch Carpodacus mexicanus B 

Red Crossbill Loxia curvirostra O 

White-winged Crossbill Loxia leucoptera O 

Common Redpoll Carduelis flammea O 

Pine Siskin Carduelis pinus b 

American Goldfinch Carduelis tristis O 

Evening Grosbeak Coccothraustes vespertinus O 

House Sparrow Passer domesticus B 

H-6 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA
 

Common Name: Mammals Scientific Name Occurrence Potential 

Masked Shrew Sorex cinereus B 

Merriam's Shrew Sorex merriami B 

Dusky Shrew Sorex monticolus b 

Dwarf Shrew Sorex nanus B 

Water Shrew Sorex palustris b 

Vagrant Shrew Sorex vagrans O 

Western Small-footed Myotis Myotis ciliolabrum O 

Long-eared Myotis Myotis evotis O 

Little Brown Myotis Myotis lucifugus O 

Fringed Myotis Myotis thysanodes O 

Long-legged Myotis Myotis volans O 

Eastern Red Bat Lasiurus borealis O 

Hoary Bat Lasiurus cinereus O 

Silver-haired Bat Lasionycteris noctivagans O 

Big Brown Bat Eptesicus fuscus O 

Spotted Bat Euderma maculatum BLM 

Townsend's Big-eared Bat Corynorhinus townsendii BLM 

Pika Ochotona princeps B 

Pygmy Rabbit Brachylagus idahoensis b 

Desert Cottontail Sylvilagus audubonii B 

Mountain Cottontail Sylvilagus nutallii O 

Snowshoe Hare Lepus americanus B 

White-tailed Jackrabbit Lepus townsendii B 

Yellow-pine Chipmunk Tamias amoenus B 

Cliff Chipmunk Tamias dorsalis b 

Least Chipmunk Tamias minimus B 

Uinta Chipmunk Tamias umbrinus B 

Yellow-bellied Marmot Marmota flaviventris B 

Uinta Ground Squirrel Spermophilus armatus B 

Wyoming Ground Squirrel Spermophilus elegans B 

Golden-mantled Ground Squirrel Spermophilus lateralis B 

Spotted Ground Squirrel Spermophilus spilosoma B 

Thirteen-lined Ground Squirrel Spermophilus tridecemlineatus B 

White-tailed Prairie Dog Cynomys leucurus B 

Black-tailed Prairie Dog Cynomys ludovicianus BLM 

Eastern Fox Squirrel Sciurus niger B 

Red Squirrel Sciurus hudsonicus B 

Wyoming Pocket Gopher Thomomys clusius B 

Northern Pocket Gopher Thomomys talpoides b 

Olive-backed Pocket Mouse Perognathus fasciatus B 

Silky Pocket Mouse Perognathus flavus b 

Great Basin Pocket Mouse Perognathus parvus B 

Ord's Kangaroo Rat Dipodomys ordii B 

Beaver Castor canadensis B 

Deer Mouse Peromyscus maniculatus B 

Pinyon Mouse Peromyscus truei B 

Northern Grasshopper Mouse Onychomys leucogaster B 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 H-7 
APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA 

Common Name: Mammals Scientific Name Occurrence Potential 

Bushy-tailed Woodrat Neotoma cinerea B 

Southern Red-backed Vole Clethrionomys gapperi B 

Western Heather Vole Phenacomys intermedius h 

Long-tailed Vole Microtus longicaudus h 

Montane Vole Microtus montanus B 

Meadow Vole Microtus pennsylvanicus B 

Sagebrush Vole Lemmiscus curtatus B 

Muskrat Ondatra zibethicus B 

Preble's Meadow Jumping Mouse Zapus hudsonius preblei BLM 

Western Jumping Mouse Zapus princeps B 

Porcupine Erethizon dorsatum B 

Coyote Canis latrans B 

Swift Fox Vulpes velox h 

Red Fox Vulpes vulpes b 

Raccoon Procyon lotor B 

Marten Martes americana b 

Short-tailed Weasel Mustela erminea b 

Long-tailed Weasel Mustela frenata b 

Black-footed Ferret Mustela nigripes h 

Mink Mustela vison b 

Badger Taxidea taxus B 

Striped Skunk Mephitis mephitis b 

Mountain Lion Puma concolor b 

Canada Lynx Lynx canadensis BLM 

Bobcat Lynx rufus B 

Elk Cervus elaphus B 

Mule Deer Odocoileus hemionus B 

White-tailed Deer Odocoileus virginianus O 

Pronghorn Antilocapra americana B 

Feral Horse Equus caballus B 

Common Name: Amphibians Scientific Name Occurrence Potential 

Tiger Salamander Ambystoma tigrinum O 

Great Basin Spadefoot Spea intermontana O 

Boreal Toad Bufo boreas boreas O 

Wyoming Toad Bufo baxteri BLM 

Northern Leopard Frog Rana pipiens O 

Boreal Chorus Frog Pseudacris maculata O 

H-8 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX H—OCCURRENCE POTENTIAL OF WILDLIFE IN THE CD-C PROJECT AREA
 

Common Name: Reptiles Scientific Name Occurrence Potential 

Ornate Box Turtle 

Many-lined Skink 

Northern Sagebrush Lizard 

Northern Plateau Lizard 

Greater Short-horned Lizard 

Pale Milksnake 

Great Basin Gophersnake 

Intermountain Wandering Gartersnake 

Plains Gartersnake 

Prairie Rattlesnake 

Terrapene ornata ornata 

Eumeces multivirgatus 

Sceloporus graciosus graciosus 

Sceloporus undulatus elongatus 

Phrynosoma hernandesi 

Lampropeltis triangulum multistriata 

Pituophis catenifer deserticola 

Thamnophis elegans vagrans 

Thamnophis radix 

Crotalus viridis viridis 

O 

H 

O 

O 

O 

H 

O 

O 

H 

O 

1 Occurrence potential of wildlife species includes direct evidence of breeding (B), indirect evidence of breeding (b), record of 

observation (O), historical record of observation (h), and historical breeding record (H) in the 1-degree grid blocks covering 41 N 

latitude and 107 W and 108 W longitude (Cerovski et al. 2004). Some species included in the table were not recorded in Cerovski et 

al. (2004), but were added on the request of the BLM-RFO. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 H-9 
 

 

APPENDIX I: WILDLIFE INVENTORY, MONITORING, AND 

PROTECTION PLAN 

Table of Contents 

1.	 Introduction.........................................................................................................................................I-1
 

2.	 Implementation Protocol.....................................................................................................................I-1
 

2.1 Annual Reports and Meetings .........................................................................................I-2 

2.1.1 Reports.............................................................................................................................I-2 

2.1.2 Meetings ..........................................................................................................................I-2 

2.2	 Annual Inventory and Monitoring .............................................................................................I-3
 

2.2.1 Special Status Species and Associated Habitat: Inventory and Monitoring
 

Protocols..........................................................................................................................I-4 

2.2.2 BLM Wyoming State Sensitive Species (Plants/Animals) and Associated 

Habitats, Inventory and Monitoring Protocols ................................................................I-6 

2.2.3 Big Game and Associated Habitats ...............................................................................I-10 

2.2.4 Raptors and Associated Habitats ...................................................................................I-10 

2.2.5 Songbirds, Waterfowl, and Shorebirds and Associated Habitats ..................................I-11 

2.2.6 Amphibians, Reptiles, and Fish and Associated Habitats .............................................I-11 

2.2.7 General Wildlife Species ...............................................................................................I-12 

2.3	 Determine and Implement Protection Measures, Effects Analysis, and Apply
 

Adaptive Management ............................................................................................................. I-12
 

2.3.1 Special Status Species and Associated Habitats: Protection Measures (Adaptive 

Management) .................................................................................................................I-13 

2.3.2 BLM Wyoming State Sensitive Species (Plants/Animals) and Associated 

Habitats: Protection Measures (Adaptive Management) ...............................................I-14 

2.3.3 Big Game Species and Associated Habitats: Protection Measures (Adaptive 

Management) .................................................................................................................I-16 

2.3.4 Raptors and Associated Habitats Protection Measures (Adaptive Management) .........I-17 

2.3.5 Songbirds, Waterfowl, and Shorebirds and Associated Habitats Protection 

Measures (Adaptive Management) ...............................................................................I-17 

2.3.6 Amphibians, Reptiles, and Fish and Associated Habitats Protection Measures 

(Adaptive Management) ................................................................................................I-17 

2.3.7 General Wildlife Species Protection Measures (Adaptive Management)......................I-18 

List of Tables 

Table I-1. Summary of general wildlife meeting and reporting requirements ........................................I-19
 

Table I-2a. Summary of references for wildlife inventory and monitoring requirements ........................I-20
 

Table I-2b. Summary of references for wildlife protection measures, cause and effect studies,
 

and adaptive management requirements: wildlife and associated habitats ...................I-26
 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-i 
 

 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

1. INTRODUCTION 

This wildlife inventory, monitoring, and protection plan was prepared in conjunction with the Continental 

Divide-Creston Environmental Impact Statement (CD-C EIS) for the CD-C project area. The BLM is 

responsible to manage for the biological integrity and habitat function of both terrestrial and aquatic 

ecosystems within the CD-C project area to sustain and optimize the distribution and abundance of all 

native, desirable non-native, and Special Status Species (Approved Rawlins Resource Management Plan 

and Record of Decision [Rawlins RMP] 2008a). The goal of the plan is to avoid and/or minimize adverse 

impacts to wildlife present on project-affected areas by: 

 monitoring wildlife population trends within and adjacent to the CD-C project area during the
 

course of project development and operations, 

 developing appropriate mitigation actions, and 

 analyzing the effectiveness of the mitigation measures. 

Implementation of the plan will provide opportunities for land managers and project personnel to achieve 

and maintain desired levels of wildlife productivity and populations within and adjacent to the CD-C 

project area (e.g., at pre-project levels) by minimizing and/or avoiding potential adverse impacts to 

wildlife species. In addition, the implementation of this plan will facilitate the maintenance of a diverse 

assemblage of wildlife populations within and adjacent to the CD-C project area simultaneously with 

development of natural gas reserves. 

Proposed inventory, monitoring, protection measures, cause and effect, and adaptive management 

mitigation will be implemented under the preferred alternative selected for the EIS. Implementation of the 

plan will begin upon the signing of the Record of Decision (ROD), and is estimated to continue for the 

life of the EIS. The plan will receive a review for effectiveness by the BLM annually. 

2. IMPLEMENTATION PROTOCOL 

This Wildlife and Plant Inventory/Monitoring, Protection/Adaptive Management, and Analysis 

Implementation Plan (Plan) contains four (4) basic steps that are required to determine if impacts are 

occurring to a species, how these impacts are occurring, what mitigation practices are required to reduce 

and/or remove these impacts, and an analysis to determine if the mitigation practices are effective in 

removing or reducing these impacts. The basis of the plan follows these four steps: 

1. Inventory/monitor species and their associated habitats; 

2. Monitor these species to determine changes in population numbers (cause and effect); 

3. Identify and implement protection measures if the population shows negative changes; and 

4. Analyze the effectiveness of the protection measures, making adjustments if required. 

This section provides preliminary information pertaining to the protocols for each of the four steps. The 

wildlife species/categories for which specific inventory, monitoring, protection, and analysis procedures 

will be applied were developed based on management agency (Bureau of Land Management [BLM], U.S. 

Fish and Wildlife Service [USFWS], Wyoming Game and Fish Department [WGFD]) and individual 

concerns identified during the preparation of the EIS and through discussion at the Monitoring without 

Borders meetings. Through annual meetings, this Plan identifies methods required to accomplish steps 1­

4 for identified species and their associated habitat types based on need, funding, and personnel 

availability for each upcoming field season and year. 

Considerable efforts will be required by agency and Operator personnel for Plan implementation each 

year. Many of the proposed annual agency data collection activities are consistent with current agency 

requirements. Additionally, during annual planning (Section 2.1.2 below) and throughout project 

implementation, all efforts will be made to accommodate agency personnel schedules and responsibilities. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-1 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

In addition, further agency cost-sharing methodologies will be considered such that public demands and 

statutory directives are achieved. 

2.1 Annual Reports and Meetings 

2.1.1 Reports 

Operators will provide the following information, in report format and following the requirements 

identified in Table I-1, to the BLM by November 15 of each calendar year: 

1.	 During project development, Operators will provide an updated inventory/monitoring report and 

description of all existing project developments (i.e., well pad location, size, roads, and associated 

level of human activity at each feature), as well as those tentatively proposed for development 

during the next 12 months in a format that is Geographic Information System (GIS) compatible; and 

2.	 Annual reports will: 

a.	 summarize annual wildlife inventory/monitoring 

b.	 summarize monitoring results, 

c.	 protection measures implemented, and effectiveness of protection measures, 

d.	 note any trends across years 

e.	 identify and assess protection measures implemented during past years, 

f.	 specify monitoring and protection measures proposed for the upcoming year, 

g.	 recommend modifications to the existing wildlife monitoring/protection plan based on the 

successes and/or failures of past years, and 

h. identify additional species/categories to be monitored. 

Where possible, the data presented in reports will be used to identify potential correlations between 

development and wildlife productivity and/or abundance, as well as sources of potential disturbance to 

wildlife. GIS will be used for information storage, retrieval, and planning, and annual GIS data updates 

will be conducted. Raw data collected each year will also be provided to other management agencies, at 

the request of the agencies. Annual reports will be prepared by the Operators’ third-party contractor with 

BLM oversight. 

The BLM will submit a final annual report to all potentially affected individuals and groups by early 

February of each year. Additional reports may be prepared in any year, as necessary, to comply with other 

relevant wildlife laws, rules, and regulations. 

2.1.2 Meetings 

A one-day meeting will be organized by the BLM and held in December (or as determined by the BLM) 

of each year to discuss and modify, as necessary, proposed wildlife inventory, monitoring, protection 

protocol, and analysis of protection measures for the subsequent year. Decisions regarding annual 

Operator-specific financing and personnel requirements will be made at these meetings. A protocol for 

accommodating previously unidentified development sites will also be determined during the annual 

meeting. Final decisions will be made by the BLM based on the input of all affected parties. Additional 

meetings may be required as necessary. 

Additional meetings may be held in any given year as necessary to inform and update cooperators on the 

findings of additional reports. 

I-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

2.2 ANNUAL INVENTORY AND MONITORING 

Inventory/monitoring is the process of gathering field data on wildlife distribution, numbers, and/or 

composition. This includes traditional wildlife range determination and habitat association inventories. It 

also encompasses population monitoring which is the process of detecting a demographic (e.g., growth 

rate, recruitment and mortality rates) or distributional change in a population over the course of repeated 

inventories and relating these changes to either natural processes (e.g., winter severity, predation) or 

human-related activities (e.g., animal harvesting, mining, forestry, urban development, etc.). Population 

monitoring may include the development and use of population models that integrate existing 

demographic information (including harvest) on a species. Inventory/monitoring also includes the process 

of compiling general (overview) information on the historical and current abundance and distribution of a 

species, its habitat requirements, rate of population change, and limiting factors (species statistics). 

Species statistics enable prioritization of animal inventories and population monitoring. All of these 

activities are included under the term inventory/monitoring (Ministry of Environment, Lands and Parks, 

November 1998). 

Monitoring studies are more site- and problem-specific than inventories. Longer-term monitoring studies 

better estimate fluctuations in wildlife uses of habitat. Conducting longer-term monitoring of wildlife 

species is more efficient and accurate for determining how certain land use practices affect wildlife and 

habitats. Inventories and monitoring procedures are grouped together here because usually the monitoring 

studies will result from the implementation of the CD-C project and will be based on a combination of 

these inventory and monitoring results. Monitoring studies involve collecting wildlife and habitat 

information over time to determine: (1) wildlife use of habitat components; (2) effects of certain land uses 

(e.g. well pads, roads, human activity in the field) on certain wildlife and habitats; (3) species or habitat 

changes caused by project implementation, as well as certain natural environmental conditions (e.g., 

drought); (4) accuracy of predictive models; (5) improvement in the accuracy of predictive models; (6) 

additional mitigation to protect wildlife and habitat in an area (i.e., from new data, new stipulations may 

be recommended or required to protect a species and its habitat); and (7) additional habitat improvement 

to benefit a species or habitat of concern. These actions can determine if the management objectives in the 

CD-C EIS are being met, can improve a biologist’s predictive models (Cooperrider et. al., 1986), and are 

basically the fundamentals of adaptive management. 

The most critical stage of implementing and completing an inventory/monitoring study is not data 

collection, presentation, or interpretation, but rather design. Years of data can be useless if a study is 

poorly designed. The use of this Plan, along with the BLM RFO Monitoring without Borders Program, 

can allow the BLM wildlife biologists to establish a flexible, systematic, and logical approach toward 

solving wildlife habitat management problems (Cooperrider et. al., 1986) within and adjacent to the CD-C 

project area. The inventory and monitoring protocols will be as identified below for each wildlife 

species/category. These protocols will be unchanged, except as authorized by the BLM or specified in this 

Plan. Additional wildlife species/categories and associated inventories and monitoring protocols may be 

added or may be omitted in future years, pending species status changes, as well as results presented in 

the coordinated review of annual reports. Opportunistic wildlife observations may be made throughout the 

year by agency and Operator personnel present in the project area. 

The frequency of inventory and monitoring requirements will be dependent upon the level of 

development in the project area. In general, frequency will increase with increased levels of development. 

Monitoring results may lead to further, currently unidentified, scientific studies specifically designed to 

determine cause and effect. The BLM will identify the level of effort required by this Plan subject to these 

categories: 

 Threatened, Endangered, Candidate, and Proposed Species (Special Status Species) 

(Plants/Animals) and associated habitats 

 BLM Sensitive Species (Plants/Animals) and associated habitats 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-3 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

 Big Game and associated habitats 

 Raptors and associated habitats 

 Song birds, waterfowl, and shorebirds and associated habitats 

 Amphibians, reptiles, and fish and associated habitats 

Although site- and species-specific surveys will be conducted in association with Application for Permit 

to drill (APD) and right-of-way application field reviews, additional large-scale field work may be 

required based on need. 

2.2.1 Special Status Species and Associated Habitat: Inventory and Monitoring 

Protocols 

The BLM is required to conduct Section 7(a) consultation (or conferencing for proposed species) under 

the Endangered Species Act of 1973 (ESA) with the USFWS if there is the potential for a proposed 

project to impact any listed species (directly or indirectly) within the CD-C project area. Listed species or 

proposed species discovered incidentally may require further investigation and consultation (BLM 2011). 

The level of inventory and monitoring required for Special Status Species will be commensurate with 

established protocols for the potentially affected species. Inventory and monitoring surveys for Special 

Status Species will be conducted by the BLM or a BLM-approved Operator-financed biologist in areas of 

potential habitat within the CD-C project area and all surveys will be conducted in coordination with the 

BLM. Methodologies and results of these surveys will be included in annual reports as required in Table 

I-1. A preliminary list of Special Status Species proposed for management and that are known to occur, or 

have the potential to occur, in the vicinity of the project area is shown in Table 3.9-3, Chapter 3 of the 

EIS. As Special Status Species are added to or withdrawn from the USFWS, BLM, and/or WGFD lists, 

appropriate modifications reflecting these changes will be incorporated into this Plan and specified in 

annual reports. 

Surveys for species or associated habitats will be implemented for the APD and/or right-of-way 

application processes. If any Special Status Species or habitats are observed, the observations will be 

noted on appropriate data forms (Table I-2a) and efforts will be made to determine species activities 

(e.g., breeding, nesting, foraging, hunting, etc.). If any management agency identifies a potential for 

concern regarding any of these species, additional inventory and monitoring and mitigation may be 

implemented as specified in annual reports. 

Special Status Species data collected during surveys and described below will be provided only as 

necessary to those requiring the data for specific management and/or project development needs. Siteand species-specific Special Status Species surveys will be conducted as necessary in association with all 

APD and right-of-way application field reviews. It should be noted that the following species or their 

associated habitats are not known to occur in the CD-C project area; therefore, inventories for these 

species will not be required at this time: Preble’s meadow jumping mouse, yellow-billed cuckoo, 

Wyoming toad, blowout penstemon plant, and the Colorado butterfly plant. The project is located outside 

of the North Platte River watershed; therefore there will be no downstream impacts from activities 

associated with the proposed CD-C project. 

Black-footed Ferret (Endangered). The USFWS, in coordination with the WGFD, has developed a list 

of habitat blocks that are not likely to be inhabited by black-footed ferrets (block cleared). In these areas, 

take of individual ferrets and effects to a wild population are not an issue and surveys for ferrets are no 

longer recommended. Although ferret surveys are not required in these areas, the area may still maintain 

value for the survival and recovery of the species in the future. The CD-C project area is located within 

three Black-footed Ferret Non-Block Cleared Areas (Complexes) which include: (1) the Continental 

Divide Complex, (2) the Desolation Flats Complex, and (3) the Dad Complex. Individual projects that are 

located within potential black-footed ferret habitat will require consultation with the BLM and WGFD 

I-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

and may require ferret surveys in areas that would likely result in a “take” of a black-footed ferret during 

project implementation. 

BLM biologists will determine the presence/absence of prairie dog colonies at each proposed 

development site during the APD and right-of-way application field reviews and determine if these 

colonies meet the requirements for potential black-footed ferret habitat. In the event that a proposed 

project cannot be relocated, surveys will be conducted as deemed necessary, during consultation with the 

BLM, WGFD and USFWS. The prairie dog colonies in the project area will be mapped and burrow 

densities determined, if required, by a BLM-approved Operator-financed biologist in association with the 

proposed development plan. Colonies that meet USFWS criteria as potential black-footed ferret habitat 

(USFWS 1989), in non-block cleared areas, will be surveyed for black-footed ferrets by a USFWScertified Operator-financed surveyor prior to BLM authorizing disturbance of these colonies. Blackfooted ferret surveys will be conducted in accordance with USFWS guidelines and approved by BLM and 

USFWS (Table I-2a). 

Greater Sage-Grouse (Candidate). Greater sage-grouse depend on extensive areas of sagebrush for food 

and cover and their strutting grounds (leks) are located in open patches with sagebrush habitat. Grouse 

exhibit site fidelity to leks, winter and summer areas. Greater sage-grouse breeding grounds (leks) 

inventories will be conducted by the BLM and WGFD within and adjacent to the project area to 

determine lek locations as deemed appropriate by the BLM. These surveys will use the WGFD protocol 

(Table I-2a). Surveys may be conducted aerially, with Operator-provided financial assistance for aircraft 

rental, based on funding availability, or on the ground, in order to determine lek locations and will follow 

the protocols identified in Table I-2a. 

Selected leks, identified by the BLM, will be monitored annually to determine lek attendance by the BLM 

or a BLM-approved Operator-financed biologist, in coordination with the WGFD and using the WGFD 

protocol (Table I-2a). Monitoring will occur between March 1 and May 15, such that all leks within the 

CD-C project area are monitored at least once every 3 years. Population trend analysis may also be 

required and will be completed with a suitable nearby reference area. The BLM will direct lek monitoring 

efforts such that efforts are made to have the same individuals monitor the same leks within and across 

years. Data collected during these surveys will be provided on a standardized form (Table I-2a). 

Helicopter surveys for wintering areas will occur when weather conditions provide the best opportunity 

for these types of surveys and will be scheduled between December 15 and February 30. These winter 

surveys should be flown at about 25 – 50 meters above ground at 1⁄4-mile intervals. These surveys are 

designed to visually identify sage-grouse and/or their tracks (BLM 2011). 

Ute Ladies’-Tresses Plant (Threatened). The Ute ladies’-tresses plant is located in riparian and wetland 

habitats between 4,300-7,000 feet in elevation. This species is not known to occur within the project area 

and the likelihood of occurrence is low; however, there is the potential of occurrence according to the 

USFWS. Locations of potential Ute ladies’-tresses plants within the CD-C project area will be mapped 

using the latest available aerial imagery, land use/land cover data (GAP and Landsat), and groundtruthing. This habitat information will be digitized into a GIS format and may be used to guide surveys 

for this threatened plant at the appropriate time of year (Table I-2a). 

Colorado River Species (Endangered). The BLM is required to conduct Section 7(a) consultation with 

the USFWS for water depletions from the Colorado River Basin. It has been determined that upstream 

water depletions from this system may have a detrimental impact on four listed fish species and their 

Critical Habitat downstream. Depletions represent an annual reduction in the volume of stream flow that 

would have reached the Critical Habitat of the four endangered fish species residing in the Colorado River 

Basin. The water depletion determination form is located in Table I-2a. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-5 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

2.2.2 BLM Wyoming State Sensitive Species (Plants/Animals) and Associated Habitats, 

Inventory and Monitoring Protocols 

BLM Sensitive Species are species designated internally in accordance with BLM Manual 6840 (BLM 

2008b). The document states: “Actions authorized by the BLM shall further the conservation/recovery of 

federally listed species and conservation of Bureau sensitive species. Bureau sensitive species will be 

managed consistent with species and habitat management objectives in land use plans...to promote their 

conservation and to minimize the likelihood and need for listing under the ESA.” 

Surveys to inventory and monitor BLM Wyoming State Sensitive Species (BLM Sensitive Species) will 

be conducted by the BLM or a BLM-approved Operator-financed biologist in areas of potential habitat 

within the CD-C project area. Information on the habitats and use of the project area is required and 

sources of this information include the BLM, Wyoming Natural Diversity Database (WYNDD), the 

WGFD, and the USFWS. In addition, surveys for site-specific species or associated habitats will be 

implemented at the APD and/or right-of-way application processes. If any BLM Sensitive Species or 

habitats are observed, the observations will be noted on appropriate data forms (Table I-2a) and efforts 

will be made to determine their activities (e.g., breeding, nesting, foraging, hunting, etc.). If any 

management agency identifies a potential for concern regarding any of these species, additional 

inventory, monitoring, and mitigation may be implemented as specified in annual reports. 

2.2.2.1 BLM Sensitive Small Mammals and Associated Habitats 

The long-eared myotis, fringed myotis, spotted bat, Townsend’s big-eared bat, pygmy rabbit, Wyoming 

pocket gopher, and white-tailed prairie dog have been identified as BLM Sensitive Species in the RFO 

and have the potential to occur within the CD-C project area. The swift fox and black-tailed prairie dog 

are also identified as BLM Sensitive Species in the RFO; however, they are not expected to occur within 

the CD-C project area. 

Bat Species (long-eared myotis, fringed myotis, spotted bat, Townsend’s big-eared bat). Long-eared 

myotis, fringed myotis, spotted bats and Townsend’s big-eared bats inhabit conifer and deciduous forests, 

caves and mines, rock crevices, man-made structures and shrublands and have been observed within the 

CD-C project area. These bats could be both resident and migratory within the project area and utilize the 

project area for feeding; however, hibernation is unlikely because suitable habitat is limited. Inventory 

and monitoring specifically for bat species within the CD-C project area has not occurred; therefore, 

impacts to these species as a result of implementing the Proposed Action within the CD-C project area are 

not known. Acoustic bat surveys, bat carcass surveys, radar surveys and mist netting surveys are four (4) 

potential inventory and monitoring techniques that could be used to identify where bat species are present 

within the project area and potential impacts to these species. There is limited information pertaining to 

impacts to bat species as a result of natural gas drilling (Table I-2a). 

Pygmy Rabbit. Pygmy rabbits are a sagebrush obligate and occur in basin prairie and riparian shrub and 

tall sagebrush in dense patches with sandy and loose soils. These rabbits are known to occur within the 

CD-C project area. The inventory and monitoring protocol for this species is identified in Table I-2a. 

Wyoming Pocket Gopher. The Wyoming pocket gopher occurs in side-hills and ridge-tops, in cushionplant communities within otherwise sagebrush-grasslands habitat. The species has the potential to occur 

within the CD-C project area. The inventory and monitoring protocol for this species is identified in 

Table I-2a. During 2009 interagency/industry survey efforts in the RFO followed WYNDD’s protocol of 

trapping for three consecutive nights or until a pocket gopher was captured. Trapping procedures need to 

consider the following: allowing trapping during the day (within reason) dependent on forecasted high 

temperatures, since pocket gophers are just as likely to backfill during the day as they are at night; and 

limiting the number of trap nights per location, as some gophers can be extremely difficult to capture or 

their burrows may become inactive over a period of time (i.e., dispersal) rendering trapping unproductive. 

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APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

White-Tailed Prairie Dog. The white-tailed prairie dog inhabits sagebrush-grasslands and is located 

within the project area. 

2.2.2.2 BLM Sensitive Upland Game Birds, Migratory Raptors, Songbirds, Shorebirds, 

Waterfowl and Habitats 

The loggerhead shrike, sage thrasher, Brewer’s sparrow, sage sparrow, white-faced ibis, trumpeter swan, 

long-billed curlew, bald eagle, ferruginous hawk, mountain plover, and burrowing owl species have been 

identified as BLM Sensitive Species in the RFO and have the potential to occur within the CD-C project 

area. These species have the potential to occur in the following habitats: 

 Loggerhead shrike, sage thrasher, Brewer’s sparrow, and sage sparrow occur within basin/prairie 

shrub and mountain foothills shrub habitats, sagebrush and are sagebrush obligate species. 

	 White-faced ibis inhabits marshes and wet meadows. 

	 Trumpeter swan inhabits lakes, ponds, and rivers. 

	 Long-billed curlew inhabits grasslands, plains, foothills and wet meadows. 

	 Bald eagle inhabits large rivers, streams and lakes, but have been observed in the project area 

primarily from November through March, forages on winter carrion and the nearest potential 

nesting habitat is along the Little Snake River nine miles south of the project area. 

	 Ferruginous hawk inhabits sagebrush-grasslands and has been found in the project area. 

	 Mountain plover inhabits grasslands and has been found within the project area. 

	 Burrowing owl has been observed in sagebrush-grasslands in the project area and has a close 

association with burrowing mammals such as prairie dogs, ground squirrels, and badgers. 

The following species are also identified as BLM Sensitive Species in the RFO; however, they are not 

expected to occur within the CD-C project area: Baird’s sparrow, Columbian sharp-tailed grouse, 

northern goshawk, and peregrine falcon. 

The BLM has responsibilities under the Migratory Bird Treaty Act (MBTA) to analyze and protect all 

migratory birds. Most of North America’s birds are migratory and migrate during the night, usually at 

higher altitudes when weather conditions are favorable. Songbirds are vulnerable to colliding with manmade structures such as buildings, communication towers, power-poles or even wind turbines during poor 

weather conditions that force them to lower altitudes (BLM 2011). 

Bird surveys are required to estimate the temporal and spatial use of the CD-C project area and vicinity by 

birds. Fixed-point count surveys can be used as a tool to inventory for songbird, raptor and other groups 

of birds. Radar surveys using marine radar surveillance can also be used to determine avian species flight 

patterns in the project area (i.e. foraging movements and migration). Multiple sampling locations should 

be identified within the selected study areas and surveyed in consultation with the BLM and WGFD 

(Table I-2a). 

Songbirds (loggerhead shrike, sage thrasher, Brewer’s sparrow, sage sparrow). Bird surveys are 

required to estimate the temporal and spatial use of the CD-C project area and vicinity by these four BLM 

Sensitive bird species. Fixed-point count surveys can be used as a tool to inventory for these birds. Radar 

surveys using marine radar surveillance can also be used to determine their flight patterns in the project 

area (i.e. foraging movements and migration). Multiple sampling locations should be identified within the 

selected study areas and surveyed in consultation with the BLM and WGFD (Table I-2a). 

Shorebirds (white-faced ibis, long-billed curlew). Ground surveys can be used during the breeding 

season, mitigation season (migratory) and the non-breeding season (winter) to determine species numbers. 

Aerial surveys and four-wheelers can be used for inaccessible areas (Table I-2a). 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-7 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Waterfowl (trumpeter swan). In the event that surveys are required, aerial surveys in the fall and midwinter will be conducted. Ground surveys can be used for areas that are inaccessible. Ground surveys are 

used to verify species composition of some swan flocks. The primary purpose of these surveys is to 

document the size of the U.S. trumpeter swan flocks and to enumerate the annual production of cygnets to 

fledgling age. The survey also provides some information on territorial occupancy and the distribution of 

failed breeders and non-breeders from year to year (USFWS 2011). 

Bald Eagle. When bald eagles are located within a proposed project area, then surveys are required that 

include nest and production surveys, winter use surveys, and eagle flight patterns and use of the project 

area throughout all phases of the project. In addition, analysis or mitigation measures necessary to comply 

with the Bald and Golden Eagle Protection Act are required by the BLM in coordination with the USFWS 

(BLM 2011). The CD-C project area does not have any known nesting habitat for bald eagles; however, 

bald eagles may fly over the area and feed in the area during certain times of the year, especially winter. 

Marine surveillance radar may be required to determine eagle flight patterns in the CD-C project area (i.e. 

foraging movements and migration). Multiple sampling locations should be identified within the area and 

surveyed in consultation with the BLM. In addition, telemetry studies (radio or satellite) may be required 

to determine eagle flight patterns in the CD-C project area (BLM 2011) 

Ferruginous Hawk. Ferruginous hawks are found in mixed-grass prairie and sagebrush steppe habitats 

during the spring, summer, and fall and generally build nests on rock outcrops, the ground, and cliff 

ledges. 

Ferruginous hawk surveys are required to: (1) identify nest densities occurring within the CD-C project 

area and (2) record nest locations to identify areas with a potential increased risk of disturbance or 

collisions for adults or young associated with nest sites (BLM 2011). Ferruginous hawk inventories will 

be conducted by the BLM at least every five years (as identified in annual reports), to determine the 

location of new nests, based on funding availability. These surveys may be implemented aerially, via 

helicopter, or from the ground. Operators may provide financial assistance for aircraft rental, based on 

funding availability. 

Breeding and nesting monitoring will be conducted annually between April and July at known nest 

locations by the BLM or a BLM-approved Operator-financed biologist, in order to ascertain nest activity 

status. Monitoring generally will be conducted from the ground, and attempts will be made to determine 

the cause of any documented nest failure. Operators may provide financial assistance for aircraft rental, as 

necessary. Site- and species-specific ferruginous hawk nest inventories will be conducted as necessary in 

association with all APD and right-of-way application field reviews. 

All nest/productivity surveys will be conducted using procedures that minimize potential adverse effects 

to nesting ferruginous hawks. Specific survey measures for reducing detrimental effects are listed in Grier 

and Fyfe (1987) and Call (1978) and include the following: 

a.	 Nest visits will be delayed for as long as possible in the nesting season; 

b.	 Nests will be approached cautiously, and their status (e.g., nestlings/fledglings) will be determined 

from a distance with binoculars/scope; 

c.	 Nests will be approached tangentially and in an obvious manner to avoid startling adults; 

d.	 Nests will not be visited during adverse weather conditions (e.g., precipitation events, windy
 

periods, and the hottest part of the day); 

e.	 Visits will be kept as brief as possible; 

f.	 All inventories will be coordinated by the BLM; 

g.	 The number of nest visits in any year will be kept to a minimum; and 

h.	 All raptor nest location data will be considered confidential. 

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APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Mountain Plover. Mountain plover breeding habitat includes short-grass prairie and shrub-steppe 

landscapes, dry land, cultivated farms, and are frequently associated with prairie dog towns. Plovers 

usually nest on sites where vegetation is sparse or absent; conditions that can be created by herbivores, 

including domestic livestock and prairie dogs. Vegetation in shortgrass prairie sites is typically less than 4 

inches tall. Nest sites within the shrub-steppe landscape are also confined to areas with little to no 

vegetation, although surrounded by areas visually dominated by shrubs. Commonly, nest sites within 

shrub-steppe areas are on active prairie dog towns. Nests are commonly located near a manure pile or 

rock. In addition to areas disturbed by prairie dogs or livestock, nests have also been found on bare 

ground created by oil and gas development activities and on dryland, cultivated agriculture in the southern 

part of their breeding range. Mountain plovers are rarely found near water. Positive indicators for 

mountain plovers therefore include level terrain, prairie dogs, bare ground, cactus pads, cattle, widely 

spaced plants, and horned larks. It would be unusual to find mountain plovers on sites characterized by 

irregular or rolling terrain, dense, matted vegetation, grass taller than 4 inches, wet soils, or the presence 

of killdeer. 

Mountain plover habitat within the CD-C EIS has been mapped within the project area; however, standard 

site-specific habitat surveys will be conducted as necessary in association with all APD and right-of-way 

application field reviews. Surveys, if required, will be conducted by the BLM or a BLM-approved 

Operator-financed biologist to detect the presence of plovers. Surveys will generally be conducted during 

the period of April 24 through May 10 to determine presence/absence of mountain plovers and June 25 

through July 10 to determine density of nesting mountain plovers (Table I-2a). These dates may change 

after consultation with the USFWS and WGFD. 

Burrowing Owl. Burrowing owls are commonly found in prairie dog towns, are migratory, breed 

throughout the plains and prairies of the western United States and winter in the southern United States 

and throughout Mexico. Federal and state laws prohibit the harming and killing of burrowing owls and 

the destruction of active nests. 

Prairie dog colonies and other suitable burrowing owl nesting areas on and within 0.75 miles of existing 

and proposed disturbance areas will be searched for western burrowing owls by the BLM from April 15 

through September 15 to determine the presence or absence of nesting owls within the CD-C project area 

(BLM 2011). If burrowing owls are found, attempts will be made to determine reproductive success. In 

addition, standard site-specific surveys will be conducted in association with all APD and right-of-way 

application field reviews. 

2.2.2.3 BLM Sensitive Amphibians, Reptiles, and Fish Species and Associated Habitats 

The northern leopard frog, Great Basin spadefoot toad, Colorado River cutthroat trout, roundtail chub, 

flannelmouth sucker, and bluehead sucker have been identified as BLM Sensitive Species in the RFO and 

have the potential to occur within the CD-C project area. The Western boreal toad and hornyhead chub 

are also identified as BLM Sensitive Species in the RFO; however, they are not expected to occur within 

the CD-C project area. 

There are no sensitive reptile species identified in the CD-C project area at this time. If species are 

identified in the future, then presence/absence surveys and hibernacula/maternity den site searches will be 

required in sensitive reptile habitat (BLM 2011) at the CD-C project area and site-specific APD and/or 

right-of-way level. 

Northern Leopard Frog and Great Basin Spadefoot Toad. Habitat mapping, Acoustic Breeding 

Surveys, and Visual Encounter Surveys (Table I-2a) can be used to determine if the northern leopard frog 

and Great Basin Spadefoot species are present within the CD-C project area and at the APD and/or rightof-way application process. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-9 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Colorado River Cutthroat Trout, Roundtail Chub, Flannelmouth Sucker, and Bluehead Sucker. At 

this time, the fish species inventory in the CD-C project area has been completed. BLM sensitive fish 

species population monitoring will continue to be conducted by the WGFD and the BLM. Monitoring for 

the associated habitats for sensitive fish species will be required and may include channel morphology, 

water quality, and in-stream habitat. 

2.2.2.4 BLM Sensitive Plant Species and Associated Habitats 

The meadow milkvetch, Cedar Rim thistle, Gibbens’ beardtongue, and persistent sepal yellowcress plants 

have been identified as BLM Sensitive Species in the RFO and have the potential to occur within the CDC project area. The many-stemmed spider flower, Laramie columbine, dune wild rye, Laramie false 

sagebrush, and limber pine are also identified as BLM Sensitive Plant Species in the RFO; however, they 

are not expected to occur within the CD-C project area. 

Locations for BLM Sensitive Plant Species within the CD-C project area will be mapped using the best 

available data from WYNDD modeling and ground-truthing. This habitat information will be digitized 

into a GIS format and may be used to guide these plant surveys at the appropriate time of the year (BLM 

2011). 

Meadow Milkvetch, Cedar Rim Thistle, Gibbens’ Beardtongue, and Persistent Sepal Yellowcress 

Plants. Sensitive plant surveys will be required within the CD-C project area. In addition, surveys for 

site-specific species or associated habitats will be implemented at the APD and/or right-of-way 

application processes to determine the potential to affect these plant species (Table I-2a). 

2.2.3 Big Game and Associated Habitats 

Data on big game use of crucial winter ranges and migration corridors within and adjacent to the project 

area will be requested by the BLM from the WGFD, as deemed necessary by the BLM. Surveys are 

required to fully understand the big game use in the project area and the associated impacts that may 

occur (BLM 2011). This information will be used to assess the effectiveness of protection measures 

implemented for the project. In the event that BLM, in consultation with the WGFD and other interested 

parties, determines that additional data should be collected for big game, these issues will be discussed at 

the annual meeting. 

Big Game Crucial Winter Range. A radio or satellite telemetry study will be developed in cooperation 

between the BLM and WGFD to monitor the use of big game crucial winter range within the CD-C 

project area. In addition, Pellet Count Surveys can be used to evaluate the seasonal spatial distribution of 

big game species based on the presence of pellet groups. 

Shrub age can be an important aspect, within mule deer habitat, often indicating that older-aged plants are 

more typical with most inventory and monitoring studies. Older plants typically produce leaders with 

greater lignin, greater secondary compounds which limit digestibility and less vigor. Current research in 

various locations (e.g., Colorado, Idaho, Nevada, Utah) have identified nutrition as an aspect currently 

limiting mule deer’s ability to increase in numbers. This occurs in both winter ranges as well as 

transitional ranges for mule deer (BLM JIO-PAPO, 2012). 

Big Game Migration Corridors. A radio or satellite telemetry study will be developed in cooperation 

between the BLM and WGFD to determine movement of big game and potential migration corridors 

within the CD-C project area. 

2.2.4 Raptors and Associated Habitats 

Raptor surveys are required to: (1) identify the species and nest densities occurring within the CD-C 

project area and (2) record raptor nest locations to identify areas with a potential increased risk of 

disturbance or collisions for adults or young associated with nest sites (BLM 2011). Raptor inventories 

I-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

will be conducted by the BLM at least every five years (as identified in annual reports), to determine the 

location of new raptor nests, based on funding availability. These surveys may be implemented aerially, 

via helicopter, or from the ground. Operators may provide financial assistance for aircraft rental, based on 

funding availability. 

Breeding and nesting monitoring will be conducted by the BLM or a BLM-approved Operator-financed 

biologist, annually, at known nest locations, between February and August, in order to ascertain nest 

activity status. Monitoring generally will be conducted from the ground, and attempts will be made to 

determine the cause of any documented nest failure. Operators may provide financial assistance for 

aircraft rental, as necessary. Site- and species-specific raptor nest inventories will be conducted as 

necessary in association with all APD and right-of-way application field reviews. 

All raptor nest/productivity surveys will be conducted using procedures that minimize potential adverse 

effects to nesting raptors. Specific survey measures for reducing detrimental effects are listed in Grier and 

Fyfe (1987) and Call (1978) and are located in Section 2.2.2.2, Inventory/Monitoring Protocol for 

Ferruginous Hawks. 

Winter use raptor surveys are required to (1) identify the species and winter densities occurring within the 

CD-C project area and (2) record raptor hunting use areas with a potential increased risk of disturbance or 

collisions for raptors to predict potential impacts. Suitable raptor perch sites such as cliffs, rock outcrops, 

man-made structures, tree tops, and areas of relatively high prey densities should be searched for hunting 

raptors. Helicopters can be used for these surveys; however, care should be taken to minimize disturbance 

to raptors during surveys (BLM 2011). 

2.2.5 Songbirds, Waterfowl, and Shorebirds and Associated Habitats 

The BLM has responsibilities under the MBTA to analyze and protect all migratory birds. Bird surveys 

are required to estimate the temporal and spatial use of the CD-C project area and vicinity by birds (see 

Section 2.2.2.2). Marine surveillance radar surveys and ground surveys such as point counts, line transect 

surveys, and spot mapping could be used to determine presence of these species. 

Point count surveys can be used as a tool to determine songbird and other groups of birds. Radar surveys 

using marine radar surveillance can also be used to determine avian species flight patterns in the project 

area (i.e. foraging movements and migration). Multiple sampling locations should be identified within the 

selected study areas and surveyed in consultation with the BLM and WGFD (Table I-2a). 

2.2.6 Amphibians, Reptiles, and Fish and Associated Habitats 

Amphibian surveys would be required since there are riparian habitats or playas within the CD-C project 

area. In addition, surveys for site-specific species or associated habitats will be implemented at the APD 

and/or right-of-way application processes to determine the potential to affect amphibians, reptile and fish 

species. 

Amphibian Species and Associated Habitats. Habitat mapping, Acoustic Breeding Surveys, and Visual 

Encounter Surveys (Table I-2a) can be used to determine amphibian species presence within the CD-C 

project area and at the APD and/or right-of-way application process. 

Reptile Species and Associated Habitats. Presence/absence surveys and hibernacula/maternity den site 

searches will be required in potential reptile habitat (BLM 2011) at the CD-C project area and sitespecific APD and/or right-of-way level. 

Fish Species and Associated Habitats. The use of hydroacoustics, gill netting, seining, and 

electrofishing by boat, canoe, or backpack can be used to measure fish abundance and distribution 

(AZGFD 2009, Taylor and Maxwell 2007). 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-11 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

2.2.7 General Wildlife Species 

BLM staff will be responsible for maintaining records of selected wildlife species observed during the 

course of their activities on the project area. Operator personnel may also provide data on wildlife 

observations. The information provided will include observations of wildlife species, their numbers, 

location, activity, and other pertinent data as applicable and identified on the General Wildlife 

Observation Data Sheet (Table I-2a). Where Operators are uncertain of the United States Geological 

Survey (USGS) coordinates for an observation, a general description of the location may be provided and 

in instances where species or sex information is questionable, Operators will identify the observation as 

such. 

Additional inventory and monitoring measures may be applied for other species as specified in annual 

reports (Table I-1). Surveys will be conducted in adherence with protocol to be established by the BLM, 

other agencies and Operators, and Operators may provide financial assistance for these inventory and 

monitoring investigations (Table I-2a). 

2.3 DETERMINE AND IMPLEMENT PROTECTION MEASURES, EFFECTS 

ANALYSIS, AND APPLY ADAPTIVE MANAGEMENT 

Long-term studies and monitoring programs identified above, along with implementing protection 

measures, should be established to evaluate and compare the effectiveness of various mitigation 

techniques. Efforts should be made to continually integrate monitoring data into adaptive management 

strategies, including making individual and compiled results available to industry and agencies to improve 

energy-development and mitigation techniques. Opportunities to enable agencies, conservation 

organizations, and energy companies to collaboratively interact and contribute data should be identified 

(WGFD 2010). Evaluations of the biological response of focal species are integral to assessing success in 

delivering conservation programs (Naugle 2011). 

During project development, the BLM is responsible to manage or restore habitat to conserve, recover, 

and maintain species populations consistent with the CD-C EIS and Rawlins RMP (BLM 2008a) plans. 

The Rawlins RMP states that a full range of mitigation options will be considered when developing 

mitigation for project-level activities, including those located within the CD-C project area. The wildlife 

protection measures proposed herein have been developed from past measures identified for oil and gas 

developments in Wyoming and are basically tools to implement while exercising adaptive management. 

Additional measures may be included and/or existing measures may be modified in any given year as 

allowable and as deemed appropriate by BLM in consultation with other agencies, Operators, and 

interested parties. These measures will be specified in annual reports (Table I-1). Protection measures 

will be implemented by Operators with assistance from and/or in consultation with the BLM. In addition, 

these measures may be modified on a site-specific basis as deemed appropriate by the BLM after 

completion of the APD and right-of-way application field reviews. 

The principal protection measure for most wildlife will be species- and project-specific measures as well 

as general wildlife and associated habitat protection measures. The implementation of these measures 

may also benefit other wildlife species found on and adjacent to the project area. Sensitive and crucial 

habitats should be avoided where possible. Protection measures (e.g., BMPs identified in the Rawlins 

RMP and CD-C EIS, Appendix C) will be applied based on the analysis of information gathered through 

inventory and monitoring. These BMPs are included in the Rawlins RMP and CD-C EIS and include, but 

are not limited to, measures such as timing restrictions to protect species and habitat from disruptive 

activities during critical periods, modifications of BLM fences to allow big game species greater freedom 

of movement to avoid disruptive activities, and vegetation treatments, such as herbicide treatments, 

seeding, prescribed burning, cutting/chopping for regeneration, planting shrubs or trees, or fertilization. 

The process of adaptive management will be used to determine the effectiveness of BMPs and necessary 

changes in conservation management will be made if identified. This process allows ineffective 

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APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

management actions to be modified, or new actions implemented, to reduce impacts to wildlife from 

development. 

The Nature Conservancy’s (TNC) Energy by Design – Cooperative Mitigation Planning for the CD-C 

Gas Field (Appendix G) is a science-based approach designed to reduce conflicts and steer development 

away from conservation priorities, increase the cost-effectiveness of mitigation, and direct funding to 

higher-value conservation. The project blends landscape-level conservation with the mitigation hierarchy 

including: (1) avoid; (2) minimize/restore; and (3) offset to improve mitigation efforts. This is 

accomplished in a four step process which includes the following; 

a.	 Develop a landscape conservation plan (or use an existing landscape plan); 

b.	 Blend landscape conservation planning with mitigation hierarchy to evaluate conservation and 

development conflicts; 

c.	 Determine the residual impacts associated with development and select an optimal offset portfolio; 

and then 

d.	 Estimate the offset contribution to conservation goals. 

TNC’s final report for the CD-C project area was completed on August 1, 2009. Protection measures and 

adaptive management for the CD-C project area could be identified from this plan. 

The Wyoming Landscape Conservation Initiative (WLCI) was created in 2007 as a multi-agency and 

stakeholders’ initiative designed to maintain and enhance wildlife habitat and other resource values within 

energy development and other changes. Partners are conducting science-based research and monitoring, 

completing habitat enhancements and restoration, encouraging effective reclamation and mitigation 

practices, identifying and prioritizing landscape-scale conservation work, and promoting grazing practices 

which benefit wildlife, ranchers, and open-space conservation. Initial funding for this program has come 

through federal appropriations and projects to date have included fence modifications and exclosure 

fencing, prescribed burns, riparian enhancements, invasive species treatments, river restoration, and 

conservation easements (WGFD 2010). Protection measures and adaptive management for the CD-C 

project area could be identified from this plan. 

2.3.1 Special Status Species and Associated Habitats: Protection Measures (Adaptive 

Management) 

The level of protection required for Special Status Species is obligatory under the ESA. If crucial features 

for any Special Status Species are found during on-site surveys of the proposed project, avoidance of 

these features will be required first. In the event this is not feasible, the BLM will conference and/or 

consult and coordinate with the USFWS to determine and implement the most effective protection 

measures required to protect Special Status Species and their habitats. Habitat and species conservation 

measures for Special Status Species are identified in the Rawlins RMP (BLM 2008a) biological 

assessment and the biological opinion. Both documents will be adhered to for compliance with the ESA 

and conservation measures will be applied to all surface-disturbing and disruptive activities, as 

appropriate. In the event that a Special Status Species is observed, especially during construction 

activities, work at the project site will be curtailed until there is concurrence between BLM and the 

USFWS on what activities can be authorized. Activities will, in most cases, be delayed until such time 

that no adverse effects will occur. 

The Rawlins RMP requires the BLM maintain, restore, or enhance Special Status Species, as well as 

Sensitive Species habitat to prevent listing under the ESA, in coordination with other local, state and 

federal agencies. It is assumed that the protocol specified for general wildlife will likely benefit Special 

Status Species as well. If any management agency identifies a potential for impacts to any Special Status 

Species, additional measures may be implemented as specified in annual reports. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-13 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Black-footed Ferret. Habitat and species conservation measures for the black-footed ferret are identified 

in the Rawlins RMP (BLM 2008a) biological assessment and the biological opinion. Both documents will 

be adhered to for compliance with the ESA and conservation measures will be applied to all surfacedisturbing and disruptive activities, as appropriate. These protection measures are identified to reduce 

impacts to the black-footed ferret within the CD-C project area (Rawlins RMP, page 2-54). If blackfooted ferrets are found on the project area, the USFWS will be notified immediately and formal 

consultations will be initiated to develop strategies that ensure no adverse effects to the species. Before 

ground-disturbing activities are initiated in black-footed ferret habitat, authorizations to proceed must be 

received from the BLM, in consultation with the USFWS. 

Greater Sage-Grouse. Habitat and species protection management actions for greater sage-grouse are 

identified in the Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts 

to the greater sage-grouse within the CD-C project area (Rawlins RMP, pages 2-54 to 2-55). Projects 

located within the Wyoming Governor’s Core Greater Sage-Grouse habitat (Executive Order 2011-5) will 

have additional protection measures attached to reduce and/or remove potential impacts to greater sagegrouse (IM WY-2012-019). To control the population of mosquitoes that might spread West Nile virus, 

larvicidal briquettes will be placed in standing water pools as appropriate. Adult mosquitoes could also be 

treated with insecticides if necessary (BLM 2008c). 

Ute Ladies’-Tresses Plant. Habitat and species conservation measures for the Ute ladies’-tresses plant 

are identified in the Rawlins RMP (BLM 2008a) biological assessment and the biological opinion. Both 

documents will be adhered to for compliance with the ESA and conservation measures will be applied to 

all surface-disturbing and disruptive activities, as appropriate. These protection measures are identified to 

reduce impacts to the Ute ladies’- tresses plant within the CD-C project area (Rawlins RMP, page 2-54). 

Colorado River Fish Species. Habitat and species conservation measures for Colorado River fish species 

are identified in the Rawlins RMP (BLM 2008a) biological assessment and the biological opinion. Both 

documents will be adhered to for compliance with the ESA and conservation measures will be applied to 

all surface-disturbing and disruptive activities, as appropriate. These protection measures are identified in 

the Rawlins RMP, page 2-54. 

2.3.2 BLM Wyoming State Sensitive Species (Plants/Animals) and Associated Habitats: 

Protection Measures (Adaptive Management) 

Surface-disturbing and disruptive activities that would potentially affect the habitat of Special Status 

Species will be intensively managed on a case-by-case basis. In addition, surface-disturbing and 

disruptive activities will be intensively managed to minimize impacts on identified crucial habitat for 

sensitive species for the purpose of protecting these species and their associated habitats. Coordination 

with the WGFD will allow the Recommendations for Development of Oil and Gas Resources Within 

Important Wildlife Habitats management actions to be implemented to reduce impacts to BLM sensitive 

species (Table I-2b). 

2.3.2.1 BLM Sensitive Small Mammals and Associated Habitats 

Bat Species (long-eared myotis, fringed myotis, spotted bat, Townsend’s big-eared bat). Habitat and 

species protection measures for BLM sensitive bat species are identified in the Rawlins RMP (BLM 

2008a). These protection measures are identified to reduce impacts to bat species within the CD-C project 

area (Rawlins RMP, page 2-54). In addition, all open vent stack equipment shall be designed and 

constructed to prevent bat use and potential mortalities. 

Pygmy Rabbit. Habitat and species protection measures for the pygmy rabbit are identified in the 

Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to the pygmy 

rabbits within the CD-C project area (Rawlins RMP, page 2-54). The BLM has identified additional 

protection measures to reduce impacts to this species. 

I-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Wyoming Pocket Gopher. Habitat and species protection measures for the Wyoming pocket gopher are 

identified in the Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts 

to the Wyoming pocket gopher within the CD-C project area (Rawlins RMP, page 2-54). To protect the 

identified Wyoming pocket gopher and associated habitat, the BLM has identified additional protection 

measures to reduce impacts to this species. The survey protocol is available from the BLM Rawlins Field 

Office upon request. 

White-tailed Prairie Dog. Habitat and species protection measures for the white-tailed prairie dog are 

identified in the Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts 

to the white-tailed prairie dog within the CD-C project area (Rawlins RMP, page 2-54 to 2-55). 

2.3.2.2 BLM Sensitive Upland Game Birds, Migratory Raptors, Songbirds, Shorebirds, 

Waterfowl and Habitats 

Habitat and species protection measures for the BLM Sensitive raptors, songbirds, shorebirds and 

waterfowl are identified in the Rawlins RMP (BLM 2008a). These protection measures are identified to 

reduce impacts to upland game birds, migratory raptors, songbirds, shorebirds, and waterfowl within the 

CD-C project area (Rawlins RMP, page 2-52 to 2-55). These are required to comply with both the 

Rawlins RMP and the MBTA. 

Songbirds (loggerhead shrike, sage thrasher, Brewer’s sparrow, sage sparrow). All open vent stack 

equipment shall be designed and constructed to prevent avian mortalities due to bird use and perching. In 

addition, nesting habitats could be treated with nitrogen fertilizers (BLM 2008c). 

Shorebirds (white-faced ibis, long-billed curlew). Protection measures that could reduce impacts to 

nesting shorebirds would be implemented on surface-disturbing and disruptive activities located near 

water habitats such as mudflats, salt ponds, marshes, rocky shores and agricultural fields (USFWS 2011). 

Waterfowl (trumpeter swan). Protection measures that could reduce impacts to waterfowl would be 

implemented on surface-disturbing and disruptive activities located near water habitats such as wetland, 

and marshes (Wetlands Regional Monitoring Program Plan 2002). In addition, not permitting the use of 

open pits (Naugle 2011) in the natural gas field would reduce impacts to waterfowl species. 

Bald Eagle and Ferruginous Hawk. Habitat and species protection measures for the bald eagle and 

ferruginous hawk are identified in the Rawlins RMP (BLM 2008a), pages 2-53 to 2-55. These protection 

measures are identified to reduce impacts to the bald eagle and ferruginous hawk within the CD-C project 

area. Protection protocol will be as described for raptors (See Section 2.3.1). Additional measures will be 

applied on a species- or site-specific basis, as deemed appropriate by the BLM and/or USFWS, and 

specified in annual reports. 

Mountain Plover. Habitat and species protection measures for the mountain plover are identified in the 

Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to the mountain 

plover within the CD-C project area (Rawlins RMP, page 2-52 to 2-55). Mountain plover habitat will be 

avoided where practical due to the presence of alternative well and road development sites. Where these 

habitats will be disturbed, reclamation will utilize procedures designed to reestablish suitable plover 

habitat. The primary protection measure for mountain plover on the project area will be avoidance plover 

habitat during the breeding season. 

Burrowing Owl. Habitat and species protection measures for the burrowing owl are identified in the 

Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to the burrowing 

owl within the CD-C project area (Rawlins RMP, page 2-53 to 2-55). 

2.3.2.3 BLM Sensitive Amphibians, Reptiles, and Fish Species and Associated Habitats 

Habitat and species protection measures for the BLM sensitive amphibian, reptile and fish species are 

identified in the Rawlins RMP (BLM 2008a), page 2-54. In addition, a portion of the Upper Muddy 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-15 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Creek/Grizzly Wildlife Habitat Management Area occurs within the CD–C project area (Rawlins RMP, 

page 2-41) which affords additional protection measures for Colorado River fish species unique to the 

Muddy Creek watershed. 

2.3.2.4 BLM Sensitive Plant Species and Associated Habitats 

Habitat and species protection measures for the BLM sensitive plant species are identified in the Rawlins 

RMP (BLM 2008a). These protection measures are identified to reduce impacts to sensitive plant species 

within the CD-C project area (Rawlins RMP, page 2-54 to 2-55). 

Operators will finance site-specific surveys for BLM Sensitive Plant Species prior to any surface 

disturbance in areas determined by the BLM to contain potential habitat for such species (BLM 2008b). 

These surveys will be completed by a qualified botanist as authorized by the BLM and this botanist will 

be subject to the BLM’s 6840 policy requirements. Data from these surveys will be provided to the BLM, 

and if any sensitive plants or habitats are found, BLM recommendations for avoidance of the proposed 

project location will be implemented (BLM 2008c). 

Meadow Milkvetch, Cedar Rim Thistle, Gibbens’ Beardtongue and Persistent Sepal Yellowcress 

Plants. In extreme cases when the proposed project cannot be relocated, then seed-banking of these plants 

from the disturbance location would be recommended to attempt off-site propagation, since most of the 

common techniques such as off-site compensation or habitat restoration have proven largely unsuccessful 

(BLM 1997). 

2.3.3 Big Game Species and Associated Habitats: Protection Measures (Adaptive 

Management) 

Big Game Crucial Winter Range. The Rawlins RMP (BLM 2008a) requires the BLM to maintain, 

restore, or enhance habitat function in crucial winter range, including those areas located within the CD-C 

project area. Habitat and species protection measures for the big game species and their habitats are 

identified in the Rawlins RMP. These protection measures are identified to reduce impacts to big game 

species within the CD-C project area (Rawlins RMP, page 2-53 to 2-54). In addition, a portion of the 

Upper Muddy Creek/Grizzly Wildlife Habitat Management Area occurs within the CD–C project area 

(Rawlins RMP, page 2-41) which affords additional protection measures for elk and mule deer crucial 

winter range. Coordination with the WGFD will allow the Recommendations for Development of Oil and 

Gas Resources Within Important Wildlife Habitats management actions to be implemented to reduce 

impacts to big game species (Table I-2b). 

Snow fences, if used, will be limited to segments of 1⁄4 mile or less. Project personnel will also be advised 

to minimize stopping and exiting their vehicles in big game winter habitat during crucial winter periods. 

In addition, escape openings will be provided along roads in big game crucial winter ranges, as designated 

by the BLM, to facilitate exit of big game animals from snowplowed roads. The use of gates on roads 

within development areas would also preclude or limit motorized public access in sensitive wildlife areas. 

Additional habitat protection and/or improvement measures may also be applied in any given year as 

directed by the BLM, in consultation with Operators and other agencies, and specified in annual reports. 

There are several projects that can be implemented to improve habitat and use for big game species which 

include, but are not limited to: (1) fertilization projects which help offset direct and indirect habitat losses 

by increasing sagebrush production, enhancing available winter forage and potentially increasing 

palatability and nutrient quality for wintering big game (specifically mule deer) (BLM 2012, BLM 

2008c); (2) closing roads from January 1-April 30 each year to protect big game from disruptive human 

activity which, during difficult winter months, can increase the mortality rate for these animals and 

patrolling the areas is required to allow the BLM to educate the public, distribute maps, answer questions, 

deter violators, encourage the public to report violations, and issue citations when needed; (3) implement 

chemical thinning treatments (tebuthioron, or SpikeTM) to increase forage variety, quantity and quality 

I-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

and improve the big sagebrush and mountain shrub age-class structure; (4) establish conservation 

easements; (5) implement fence modification projects; (6) implement prescribed fire treatments for big 

game species (e.g., spring and fall ranges should focus on herbaceous component to help does with 

fawning and winter ranges should focus more on shrubs and shrub productivity); (7) seeding after fires; 

(8) mechanical treatments such as crushing with an aerator and including seeding in the treatment; (9) 

chaining, disking and imprinting pipe harrowing and aerating; (10) mowing; (11) other vegetation 

treatments such as planting of shrubs and aspen; and (12) control of invasive weeds (BLM 2012). 

Big Game Migration Corridors. Big game migration corridor habitat protection measures are identified 

in the Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to big 

game species within the CD-C project area (Rawlins RMP, page 2-54). Surface-disturbing and disruptive 

activities will be managed, on a case-by-case basis, in identified big game migration and transitional 

ranges to maintain their integrity and function for big game species in these areas. Although fences are 

not a direct result of natural gas development, fences that are identified to be a problem to big game 

migration, as a result of development, will be modified to meet BLM fence standards. New fences are 

allowed in big game migration corridors, provided they meet BLM fence standards. 

2.3.4 Raptors and Associated Habitats Protection Measures (Adaptive Management) 

The primary protection measure for raptor species on the project area will be avoidance of nest locations 

during the breeding season. Habitat and species protection measures for raptor species are identified in the 

Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to raptor species 

within the CD-C project area (Rawlins RMP, page 2-53). Coordination with the WGFD will allow the 

Recommendations for Development of Oil and Gas Resources Within Important Wildlife Habitats 

management actions to be implemented to reduce impacts to raptor species (Table I-2b) 

The goshawk, osprey, and screech owl raptor species are located within the RFO area; however, they 

require different habitat types than those located within the CD-C project area and are highly unlikely to 

nest within the project area. In the rare event that one of these species is found, their breeding and nesting 

habitat will be protected by the protection measures found in the Rawlins RMP. 

2.3.5 Songbirds, Waterfowl, and Shorebirds and Associated Habitats Protection 

Measures (Adaptive Management) 

Habitat and species protection measures for songbirds, waterfowl, and shorebirds species are identified in 

the Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to songbirds, 

waterfowl, and shorebirds within the CD-C project area (Rawlins RMP, page 2-52 to 2-54). All open vent 

stack equipment shall be designed and constructed to prevent use birds and to discourage perching. 

Surface-disturbing and disruptive activities will be intensively managed. BMPs will be applied to surfacedisturbing and disruptive activities to maintain or enhance habitat for these species ((BLM 2008a). 

Coordination with the WGFD will allow the Recommendations for Development of Oil and Gas 

Resources Within Important Wildlife Habitats management actions to be implemented to reduce impacts 

to songbirds, waterfowl, and shorebird species (Table I-2b) 

2.3.6 Amphibians, Reptiles, and Fish and Associated Habitats Protection Measures 

(Adaptive Management) 

Habitat and species protection measures for amphibian, reptile and fish species are identified in the 

Rawlins RMP (BLM 2008a). These protection measures are identified to reduce impacts to the 

amphibians, reptiles, and fish within the CD-C project area (Rawlins RMP, page 2-54). Coordination with 

the WGFD will allow the Recommendations for Development of Oil and Gas Resources Within Important 

Wildlife Habitats management actions to be implemented to reduce impacts to amphibian, reptile, and fish 

species (Table I-2b) 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-17 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

2.3.7 General Wildlife Species Protection Measures (Adaptive Management) 

The Rawlins RMP (BLM 2008a) requires the BLM manage projects through facility placement and 

minimization of construction disturbance to maintain connectivity between large contiguous blocks of 

undisturbed habitat. Reclamation activities associated with proposed projects within the CD-C project 

area must include wildlife habitat objectives in the plans. 

Unless otherwise indicated, the following protection measures will be applied for all wildlife species. 

Additional measures primarily designed to minimize impacts to other resources (e.g., vegetation and 

surface water resources, including wetlands, steep slopes, etc.) are identified in the EIS in Chapter 4, and 

these measures may provide additional protection for wildlife. Additional actions may be applied in any 

given year to further minimize potential impacts to wildlife. These actions will be specified in annual 

reports. 

All roads on and adjacent to the project area that are required for the proposed project will be 

appropriately constructed, improved, maintained, and signed to minimize potential wildlife and vehicle 

collisions and facilitate wildlife (most notably big game) movement through the project area. Appropriate 

speed limits will be adhered to on all project roads, and Operators will advise employees and contractors 

regarding these speed limits. Some existing roads on the project area and surrounding transportation 

planning area may be reclaimed if they become redundant, and/or closed (gated and locked, year-round or 

seasonally) to deny unnecessary access. 

To protect important habitat in portions of the project area (i.e., ephemeral draws dominated by basin big 

sagebrush), areas with sagebrush greater than three feet tall will be avoided where possible. 

Additional non-species-specific wildlife mitigations that may reduce and/or eliminate potential impacts to 

species and associated habitats include the following: 

a.	 Reserve, work-over, and flare pits and other locations potentially hazardous to wildlife will be 

adequately protected by netting and/or fencing as directed by the BLM to prohibit wildlife access. 

b.	 If dead or injured raptors, big game, migratory birds, or unusual wildlife are observed on the project 

area, Operator personnel will contact the appropriate BLM and WGFD offices. Under no 

circumstances will dead or injured wildlife be approached or handled by Operator personnel. 

c.	 Employee and contractor education will be conducted regarding wildlife laws. If violations are 

discovered on the project area, Operators will immediately notify the appropriate agency. If the 

violation is committed by an employee or contractor, said employee or contractor will be disciplined 

and may be dismissed by the Operator and/or prosecuted by the WGFD and/or USFWS. 

d.	 Operators will implement policies designed to control off-site activities of operation personnel and 

littering, and will notify all employees (contract and company) that conviction of a violation can 

result in disciplinary action, including dismissal. 

e.	 Use of smaller rigs, directional drilling, oak mats, and purpose-built rigs. 

f.	 When studies become available that indicate the need for changes, modifications of timing or other 

stipulations would be implemented or deleted based on the findings. 

Additional project- and site-specific mitigation measures may be added in future years, as specified in 

annual reports. 

I-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-1: Summary of general wildlife meeting and reporting requirements 

Action Dates Responsible Entity 

Annual tentative plan of development By November 15, annually Operator using format identified in 

Table I-2a 

Annual inventory, monitoring, 

protection measures, and effects 

analysis data will be completed 

By November 15, annually Operator using format identified by 

the BLM for the annual report 

Annual reports Annually: Final–early February BLM will review and determine if 

requirements are being met 

Annual meeting December and as necessary BLM with participation by other 

agencies and Operators 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-19 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2a: Summary of references for wildlife inventory and monitoring requirements 

Special Status Species; BLM Sensitive Species; Big Game Crucial Winter Range and Migration Corridors; 

Raptors; Songbirds, Waterfowl, and Shorebirds; Amphibians, Reptiles, and Fish; and General Wildlife 

Species and Associated Habitats located within and adjacent to the CD-C project area (Operators will be 

required to use the inventory and monitoring protocols identified below for each species in this table. Changes to the 

protocols will be based on decisions made by the BLM and will be discussed at the Monitoring without Borders 

Meetings held each year and at other meetings as deemed appropriate) 

Species / Associated Habitat Inventory and Monitoring Requirements 

Threatened, Endangered, Candidate, and Proposed Species (Special Status Species) 

Black-footed Ferret (E) 

(Mustela nigripes) 

(CD/WII EIS [BLM 2000] and BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; 

Appendices 8,10,10,14,17, 26 and 36) 

Habitat, Species: WGFD: WY Wyoming State Wildlife Action Plan- 2010 (WY 

SWAP 2010) Species Accounts p. IV-2-20 to 2-11; Habitat Section-Sagebrush 

Shrublands p. III-9-12 to 9-15, Desert Shrublands p. III-3-8 to 3-10 

USFWS 1989. Black-footed Ferret Survey Guidelines for Compliance with the 

Endangered Species Act. Denver, Colorado, and Albuquerque, New Mexico: U.S. 

Fish and Wildlife Service. April 1989. 10 pp. + appendices. 

Greater Sage-Grouse (C) 

(Centrocercus urophasianus) 

Annually from March to mid-May to determine lek activity. BLM or BLM-approved 

Operator-financed biologist. WGFD standard protocols/form required for grouse 

lek monitoring 

(CD/WII EIS [BLM 2000] and BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; 

Appendices 8,10,15,17,26 and 36) 

At least every five years. BLM or BLM-approved Operator-financed biologist with 

Operator-provided financial assistance for aircraft rental will inventory for new 

leks. RFO (CD/WII EIS [BLM 2000] and BLM 2008a Wildlife and Fisheries p. 2-51 

to 2-55; Appendices 8,10,15,17,26 and 36) 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-69 to 1-70; 

Habitat Section-Sagebrush Shrublands p. III-9-12 to 9-15, Desert Shrublands p. 

III-3-8 to 3-10 

Greater Sage-Grouse Habitat Management Policy on Wyoming Bureau of Land 

Management (BLM) Administered Public Lands including the Federal Mineral 

Estate. Instruction Memorandum No. WY-2010-012. December 29, 2009. EMS 

Transmission: January 4, 2010. 

Wyoming Game and Fish Department Greater Sage-Grouse Lek Monitoring 

Techniques. 

Monitoring Techniques, Survey Types: Bureau of Land Management High 

Desert District Wildlife and Plant Survey Protocols for Wind Energy Development. 

Pages 11-12 and Appendix C. 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

In order to resolve conflicts with vegetation treatments adjacent to and within the 

CD-C project area, refer to the nine (9) steps in the Wyoming Guidelines for 

Managing Sagebrush Communities with an Emphasis on Fire Management 

(Wyoming Interagency Vegetation Committee 2002:12) 

Ute Ladies’-Tresses Plant (T) 

(Spiranthes diluvialis) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,14,15,17,26 

and 36; Vegetation p. 2-46 to 2-48. 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Rare Plant Mapping: Bureau of Land Management High Desert District Wildlife 

and Plant Survey Protocols for Wind Energy Development. Page13. 

BLM Buffalo Field Office Wildlife Surveys; 

<http://www.blm.gov/wy/st/en/field_offices/Buffalo/wildlife.html> 

I-20 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2a: Summary of references for wildlife inventory and monitoring requirements, continued 

Species / Associated Habitat Inventory and Monitoring Requirements 

Colorado River Fish Species: 

bonytail (Gila elegans), 

Colorado pikeminnow 

(Ptychocheilus lucius), 

humpback chub (Gila cypha), 

razorback sucker (Xyrauchen 

texanus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Protection Measures: Bureau of Land Management High Desert District Wildlife 

and Plant Survey Protocols for Wind Energy Development. Appendix H. 

BLM Sensitive Species 

Bat species: long-eared myotis 

(Myotis evotis), fringed myotis 

(Myotis thysanodes), spotted 

bat (Euderma maculatum), 

Townsend’s big-eared bat 

(Corynorhinus townsendii) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP Species Accounts p. IV-2-41, p. IV-2-27, p. 

IV-2-77 and p. IV-2-84; spotted bat- Habitat Section-Sagebrush Shrublands p. III-9-

12 to 9-15, Aspen/Deciduous Forest p. III-1-11 to 1-13, Cliffs-Canyons-Caves and 

Rock Outcrops p. III-2-8 to 2-10, Habitat Section-Riparian p. III-8-14 to 8-18, 

Wetlands p. III-10-11 to 10-13 

Bat Carcass Survey, Bat Protection Plan: Bureau of Land Management High 

Desert District Wildlife and Plant Survey Protocols for Wind Energy Development. 

Page 3 and Appendix A. 

Goodbar, J. R. 1999. Oil and Gas Drilling in Cave and Karst Areas: A Process of 

Mitigating Impacts. Proceedings of the 1997 Karst and Cave Management 

Symposium, 13th National Cave Management Symposium, Bellingham, 

Washington and Chilliwack and Vancouver Island, BC, Canada, October 7-10, 

1997. pp. 195-197. 

Bat Conservation International. Media and Information Literature Database. 

Literature Library. www.batcon.org 

Pygmy rabbit (Sylvilagus 

idahoensis) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-2-70; Habitat 

Section-Sagebrush Shrublands p. III-9-12 to 9-15, Aspen/Deciduous Forest p. III-1-

11 to 1-13 

Survey Protocol: Bureau of Land Management High Desert District Wildlife and 

Plant Survey Protocols for Wind Energy Development. Appendix F. 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

Wyoming pocket gopher 

(Thomomys clusius) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-2-97, Desert 

Shrublands p. III-3-8 to 3-10 

Survey Protocol, Sampling Techniques: Bureau of Land Management High 

Desert District Wildlife and Plant Survey Protocols for Wind Energy Development. 

Appendix I. 

White-tailed prairie dog 

(Cynomys gunnisoni) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-21 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2a: Summary of references for wildlife inventory and monitoring requirements, continued 

Species / Associated Habitat Inventory and Monitoring Requirements 

Swift Fox (Vulpes velox) BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, p. IV-2-81; Habitat 

Section- Sagebrush Shrublands p. III-9-12 to 9-15 

Songbirds: loggerhead shrike 

(Lanius ludovicianus), sage 

thrasher (Oreoscoptes 

montanus), Brewer’s sparrow 

(Spizella breweri), sage 

sparrow (Amphispiza belli) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-29, p. IV-1-

112 and p. IV-1-114; Habitat Section-Sagebrush Shrublands p. III-9-12 to 9-15, 

Foothill Shrublands p. III-4-10 to 4-12 

Fixed Point Count Surveys and Marine Surveillance Radar Surveys: Bureau of 

Land Management High Desert District Wildlife and Plant Survey Protocols for 

Wind Energy Development. pp 3 – 11. 

Shorebirds: white-faced ibis 

(Plegadis chihi), long-billed 

curlew (Numenius americanus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-85 and p. IV1-136, Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

Species Survey, Monitoring: U. S. Shorebird Conservation Plan: A 

Comprehensive Monitoring Program for North American Shorebirds. 2000. Pages 

80-81 

Wetlands Regional Monitoring Program Plan 2002, Part 2: Data Collection 

Protocols Shorebirds, Gary W. Page, Point Reyes Bird Observatory, Stinson Beach 

CA and Nils Warnock, Point Reyes Bird Observatory, Stinson Beach CA 

Waterfowl: trumpeter swan 

(Cygnus buccinator) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-125, Habitat 

Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Trumpeter Swan Survey of the Rocky Mountain Population Winter 2011, U.S. Fish 

and Wildlife Service Migratory Birds and State Programs Mountain-Prairie Region 

Lakewood, Colorado, April 12, 2011 <http://www.fws.gov/mountainprairie/species/birds/trumpeterswan/trumpeter_swan_survey_winter_2011.pdf> 

USFWS Red Rock Lakes National Wildlife Refuge. Mountain-Prairie Region. March 

1, 2011 <http://www.fws.gov/redrocks/Refuge-Management-Trumpeter-Swan.htm> 

Bald eagle (Haliaeetus 

leucocephalus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,14,15,17,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-8, Habitat 

Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Field Protocol for Spatially-Balanced Sampling of Landbird Populations. Hanni, 

D.J., C.M. White, R.A. Sparks, J.A. Blakesley, G.J. Levandoski, and J.J. Birek. 

2010. Unpublished report. Rocky Mountain Bird Observatory, Brighton, CO. 34pp. 

Survey Protocol, Raptor Nesting/Habitat Surveys: Bureau of Land Management 

High Desert District Wildlife and Plant Survey Protocols for Wind Energy 

Development. pp3 – 11 and Appendix G 

Ferruginous hawk (Buteo 

regalis) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-55; Habitat 

Section-Sagebrush Shrublands p. III-9-12 to 9-15 

Field Protocol for Spatially-Balanced Sampling of Landbird Populations. Hanni, 

D.J., C.M. White, R.A. Sparks, J.A. Blakesley, G.J. Levandoski, and J.J. Birek. 

2010. Unpublished report. Rocky Mountain Bird Observatory, Brighton, CO. 34pp. 

I-22 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2a: Summary of references for wildlife inventory and monitoring requirements, continued 

Species / Associated Habitat Inventory and Monitoring Requirements 

Fixed Point Count Surveys and Marine Surveillance Radar Surveys: Bureau of 

Land Management High Desert District Wildlife and Plant Survey Protocols for 

Wind Energy Development. pp3 – 11 

Raptor Nesting/Habitat Surveys: Bureau of Land Management High Desert 

District Wildlife and Plant Survey Protocols for Wind Energy Development. 

Appendix G. 

Mountain plover (Charadrius 

montanus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-92, Habitat 

Section-Desert Shrublands p. III-3-8 to 3-10 

Mountain Plover Survey Guidelines. U.S. Fish and Wildlife Service. March 2002. 

Annually from May to July. BLM or BLM-approved Operator-financed biologist. 

Standard form required for mountain plover monitoring. 

Survey Protocol, Survey Guidelines: Bureau of Land Management High Desert 

District Wildlife and Plant Survey Protocols for Wind Energy Development. Page 12 

and Appendix D. 

Species Survey, Monitoring: U. S. Shorebird Conservation Plan: A 

Comprehensive Monitoring Program for North American Shorebirds. 2000. Pages 

60-61 

Burrowing owl (Athene 

cunicularia) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-33; Habitat 

Section-Sagebrush Shrublands p. III-9-12 to 9-15, Desert Shrublands p. III-3-8 to 

3-10 

Survey Protocol: Bureau of Land Management High Desert District Wildlife and 

Plant Survey Protocols for Wind Energy Development. Page 8 and Appendix B. 

Amphibians: northern leopard 

frog (Rana pipiens), Great 

Basin spadefoot toad (Spea 

intermontana) 

BLM 2008 Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-4-9, Habitat 

Section-Riparian p. III-8-14 to 8-18, Foothill Shrublands p. III-4-10 to 4-12, 

Wetlands p. III-10-11 to 10-13 

Habitat, Acoustic and Visual Survey Protocol: Bureau of Land Management 

High Desert District Wildlife and Plant Survey Protocols for Wind Energy 

Development. Page 7. 

Fish: Colorado River cutthroat 

trout (Oncorhynchus clarkii 

pleuriticus), roundtail chub 

(Gila robusta), flannelmouth 

sucker (Catostomus latipinnis), 

and bluehead sucker 

(Catostomus discobolus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-3-19, p. IV-3-

68, p. IV-3-28 and p. IV-3-3; III-13-17 thru 13-19; Aquatic Basins p. III-13-17 to 13-

19, Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

AZ Game and Fish Department Fish Survey Techniques 2009. 

<http://www.azgfd.gov/w_c/Fish_Survey_Techniques.shtml> 

Hydroacoustics: Lakes and Reservoirs. J. Christopher Taylor and Suzanne L. 

Maxwell. <http://www.stateofthesalmon.org/fieldprotocols/downloads/SFPH_p5-

.pdf> 

Meadow milkvetch plant 

(Astragalus diversifolius var. 

diversifolius) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Cedar Rim thistle plant 

(Cirsium aridum) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Habitat Section-Desert Shrublands p. 

III-3-8 to 3-10, Cliffs-Canyons-Caves and Rock Outcrops p. III-2-8 to 2-10 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-23 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2a: Summary of references for wildlife inventory and monitoring requirements, continued 

Species / Associated Habitat Inventory and Monitoring Requirements 

Gibbens’ beardtongue plant 

(Penstemon gibbensii) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Habitat Section-Desert Shrublands p. 

III-3-8 to 3-10, Cliffs-Canyons-Caves and Rock Outcrops p. III-2-8 to 2-10 

Persistent sepal yellowcress 

plant (Rorippa calycina) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Big Game Crucial Winter Range, Migration Corridors, and Associated Habitats 

Big Game Crucial Winter Range BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8, 9,15,17,26 and 

36 

WGFD: BLM will request data from WGFD 

Habitat, Species: WGFD: Habitat Section Sagebrush Shrublands p. III-9-12 to 9-

15, Foothill Shrublands p. III-4-10 to 4-12, Desert Shrublands p. III-3-8 to 3-10 

Radio or satellite telemetry to determine big game movement 

Pellet Count Surveys 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

Big Game Migration Corridors BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,9,15,17,26 and 

36 

Habitat, Species: WGFD: Habitat Section Sagebrush Shrublands p. III-9-12 to 9-

15, Foothill Shrublands p. III-4-10 to 4-12, Desert Shrublands p. III-3-8 to 3-10 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

Raptors and Associated Habitats 

Raptors (Non-Special Status 

Species and BLM Sensitive 

Species) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-other bird species 

Annually from April to July to determine nest activity. BLM or BLM-approved 

Operator-financed biologist. Standard form required for raptor nest monitoring 

At least every five years. BLM or BLM-approved Operator-financed biologist with 

Operator-provided financial assistance for aircraft rental. 

Field Protocol for Spatially-Balanced Sampling of Landbird Populations. Hanni, 

D.J., C.M. White, R.A. Sparks, J.A. Blakesley, G.J. Levandoski, and J.J. Birek. 

2010. Unpublished report. Rocky Mountain Bird Observatory, Brighton, CO. 34pp. 

Survey Protocol, Avian Protection Plan: Bureau of Land Management High 

Desert District Wildlife and Plant Survey Protocols for Wind Energy Development. 

p. 3 – 11 for Fixed Point Count Surveys and Marine Surveillance Radar Surveys. 

Bureau of Land Management High Desert District Wildlife and Plant Survey 

Protocols for Wind Energy Development. Appendix G. 

I-24 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2a: Summary of references for wildlife inventory and monitoring requirements, continued 

Species / Associated Habitat Inventory and Monitoring Requirements 

Songbirds, Waterfowl, and Shorebirds and Associated Habitats 

Songbirds, waterfowl, and 

shorebirds and associated 

habitats (Non-Special Status 

Species and BLM Sensitive 

Species) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-other bird species, Habitat Section-Riparian p. III-8-

14 to 8-18 – other species 

Field Protocol for Spatially-Balanced Sampling of Landbird Populations. Hanni, 

D.J., C.M. White, R.A. Sparks, J.A. Blakesley, G.J. Levandoski, and J.J. Birek. 

2010. Unpublished report. Rocky Mountain Bird Observatory, Brighton, CO. 34pp. 

Survey Protocol: Bureau of Land Management High Desert District Wildlife and 

Plant Survey Protocols for Wind Energy Development. pp3 – 11 for Fixed Point 

Count Surveys and Marine Surveillance Radar Surveys. 

Species Survey, Monitoring: U. S. Shorebird Conservation Plan: A 

Comprehensive Monitoring Program for North American Shorebirds. 2000. Pages 

60-61, 80-81 

Amphibians, Reptiles, and Fish and Associated Habitats 

Amphibians, reptiles, and fish 

and associated habitats (NonSpecial Status Species and 

BLM Sensitive Species) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,10,14,15,17,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-other amphibian, reptile and fish species; WY SWAP 

2010 Aquatic Basins p. III-13-17 to 13-19 – other fish species, Habitat SectionRiparian p. III-8-14 to 8-18 – other species 

Habitat Mapping, Acoustic Breeding Surveys, Visual Surveys 

Amphibians/Reptiles: Bureau of Land Management High Desert District Wildlife 

and Plant Survey Protocols for Wind Energy Development, p 7. 

AZ Game and Fish Department Fish Survey Techniques. 2009. 

<http://www.azgfd.gov/w_c/Fish_Survey_Techniques.shtml> 

Hydroacoustics: Lakes and Reservoirs (Taylor and Maxwell 2007) 

<http://www.stateofthesalmon.org/fieldprotocols/downloads/SFPH_p5.pdf> 

General Wildlife Species and Associated Habitats 

General Wildlife Species BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 8,14,15,17,26 and 

36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-crustacean and mollusk species 

General Wildlife Observation Data Sheet. Surveys will be conducted in adherence 

with protocol to be established by the BLM, other agencies and Operators and 

Operators may provide financial assistance for these investigations 

Additional inventory and monitoring measures may be applied for other species as 

specified in annual reports. BLM with participation by other agencies and 

Operators. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-25 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2b.	 Summary of references for wildlife protection measures, cause and effect studies, 

and adaptive management requirements: wildlife and associated habitats 

Special Status Species; BLM Sensitive Species; Big Game Crucial Winter Range and Migration Corridors; 

Raptors; Songbirds, Waterfowl, and Shorebirds; Amphibians, Reptiles, and Fish; and General Wildlife 

Species and associated habitats located within and adjacent to the CD-C project area (Operators will be 

required to use the inventory and monitoring protocols identified below for each species in this table. Changes to the 

protocols will be based on decisions made by the BLM and will be discussed at the Monitoring without Borders 

Meetings held each year and other meetings as deemed appropriate) 

Species / Habitat Protection Measures, Cause and Effect Studies and Adaptive Management 

Requirements 

Threatened, Endangered, Candidate, and Proposed Species (Special Status Species) 

and Associated Habitats 

Black-footed Ferret (E) 

(Mustela nigripes) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,14,15,17,18,26 and 36 

Habitat, Species: WGFD: WY Wyoming State Wildlife Action Plan- 2010 (WY 

SWAP 2010) Species Accounts p. IV-2-20 to 2-11; Habitat Section-Sagebrush 

Shrublands p. III-9-12 to 9-15, Desert Shrublands p. III-3-8 to 3-10 

Greater Sage-Grouse (C) 

(Centrocercus urophasianus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-69 to 1-70; 

Habitat Section-Sagebrush Shrublands p. III-9-12 to 9-15, Desert Shrublands p. 

III-3-8 to 3-10 

Greater Sage-Grouse Habitat Management Policy on Wyoming Bureau of Land 

Management (BLM) Administered Public Lands including the Federal Mineral 

Estate. Instruction Memorandum No. WY-2010-012. December 29, 2009. EMS 

Transmission: January 4, 2010. 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

In order to resolve conflicts with vegetation treatments adjacent to and within the 

CD-C project area, refer to the nine (9) steps in the Wyoming Guidelines for 

Managing Sagebrush Communities with an Emphasis on Fire Management 

(Wyoming Interagency Vegetation Committee 2002:12) 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Ute Ladies’-Tresses Plant (T) 

(Spiranthes diluvialis) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,14,15,17,18,24,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Colorado River Fish Species: 

bonytail (Gila elegans), 

Colorado pikeminnow 

(Ptychocheilus lucius), 

humpback chub (Gila cypha), 

razorback sucker (Xyrauchen 

texanus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

I-26 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2b. Summary of references for wildlife protection measures, cause and effect studies, and 

adaptive management requirements: wildlife and associated habitats, continued 

Species / Habitat Protection Measures, Cause and Effect Studies, and Adaptive Management 

Requirements 

BLM Sensitive Species (Plants/Animals) and Associated Habitats 

Bat species: long-eared 

myotis (Myotis evotis), 

fringed myotis (Myotis 

thysanodes), spotted bat 

(Euderma maculatum), 

Townsend’s big-eared bat 

(Corynorhinus townsendii) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP Species Accounts p. IV-2-41, p. IV-2-27, p. 

IV-2-77 and p. IV-2-84; spotted bat- Habitat Section-Sagebrush Shrublands p. III9-12 to 9-15, Aspen/Deciduous Forest p. III-1-11 to 1-13, Cliffs-Canyons-Caves 

and Rock Outcrops p. III-2-8 to 2-10, Habitat Section-Riparian p. III-8-14 to 8-18, 

Wetlands p. III-10-11 to 10-13 

Bat Carcass Survey Protocol, Bat Protection Plan: Bureau of Land 

Management High Desert District Wildlife and Plant Survey Protocols for Wind 

Energy Development. Page 3 and Appendix A. Bat Carcass Survey 

Goodbar, J. R. 1999. Oil and Gas Drilling in Cave and Karst Areas: A Process of 

Mitigating Impacts. Proceedings of the 1997 Karst and Cave Management 

Symposium, 13th National Cave Management Symposium, Bellingham, 

Washington and Chilliwack and Vancouver Island, BC, Canada, October 7-10, 

1997. pp. 195-197. 

Acoustic, Carcass, Mortality Surveys: SWCA Environmental Consultants. 

Avian and Bat Protection Plan for the Spring Valley Wind Energy Facility. 2010. 

Prepared for Spring Valley Wind LLC, 1600 Smith Street, Suite 4025, Houston, 

Texas 77002. Prepared by SWCA Environmental Consultants, 7373 Peak Drive, 

Suite 170, Las Vegas, Nevada 89128. 

Bat Conservation International. Media and Information Literature Database. 

Literature Library. www.batcon.org 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Pygmy rabbit (Sylvilagus 

idahoensis) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,15,17,18,26 and 

36; RFO Wildlife Attachment 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-2-70; Habitat 

Section-Sagebrush Shrublands p. III-9-12 to 9-15, Aspen/Deciduous Forest p. III1-11 to 1-13 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Wyoming pocket gopher 

(Thomomys clusius) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36; RFO Wildlife Attachment 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-2-97, Desert 

Shrublands p. III-3-8 to 3-10 

Surveys, Sampling Approach: Bureau of Land Management High Desert District 

Wildlife and Plant Survey Protocols for Wind Energy Development. Appendix I. 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-27 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2b. Summary of references for wildlife protection measures, cause and effect studies, and 

adaptive management requirements: wildlife and associated habitats, continued 

Species / Habitat Protection Measures, Cause and Effect Studies, and Adaptive Management 

Requirements 

White-tailed prairie dog 

(Cynomys gunnisoni) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,14,15,17,18,26 and 36 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Swift Fox (Vulpes velox) BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

WGFD: WY SWAP 2010 Species Accounts, p. IV-2-81; Habitat SectionSagebrush Shrublands p. III-9-12 to 9-15 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Songbird: loggerhead shrike 

(Lanius ludovicianus), sage 

thrasher (Oreoscoptes 

montanus), Brewer’s sparrow 

(Spizella breweri), sage sparrow 

(Amphispiza belli) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-29, p. IV-1-

112 and p. IV-1-114; Habitat Section-Sagebrush Shrublands p. III-9-12 to 9-15, 

Foothill Shrublands p. III-4-10 to 4-12 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Shorebirds: white-faced ibis 

(Plegadis chihi), long-billed 

curlew (Numenius americanus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-85 and p. 

IV-1-136, Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-

13 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Waterfowl: trumpeter swan 

(Cygnus buccinator) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-125, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

Energy Development and Wildlife Conservation in Western North America, David 

E Naugle 2011. 

Wetlands Regional Monitoring Program Plan 2002, 

Part 2: Data Collection Protocols Wetland Birds, Wetland Bird Monitoring, 

Developed by the Bird Focus Group 

Wetland Regional Monitoring Program 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

I-28 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2b. Summary of references for wildlife protection measures, cause and effect studies, and 

adaptive management requirements: wildlife and associated habitats, continued 

Species / Habitat Protection Measures, Cause and Effect Studies, and Adaptive Management 

Requirements 

Bald eagle (Haliaeetus 

leucocephalus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,14,15,17,18,26 and 36; RFO Wildlife Attachment 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-8, Habitat 

Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Field Protocol for Spatially-Balanced Sampling of Landbird Populations. Hanni, 

D.J., C.M. White, R.A. Sparks, J.A. Blakesley, G.J. Levandoski, and J.J. Birek. 

2010. Unpublished report. Rocky Mountain Bird Observatory, Brighton, CO. 34pp. 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Ferruginous hawk (Buteo 

regalis) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-55; Habitat 

Section-Sagebrush Shrublands p. III-9-12 to 9-15 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Mountain plover (Charadrius 

montanus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36; RFO Wildlife Attachment 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-92, Habitat 

Section-Desert Shrublands p. III-3-8 to 3-10 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Burrowing owl (Athene 

cunicularia) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36; RFO Wildlife Attachment 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-1-33; Habitat 

Section-Sagebrush Shrublands p. III-9-12 to 9-15, Desert Shrublands p. III-3-8 to 

3-10 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Amphibians: northern leopard 

frog (Rana pipiens), Great Basin 

spadefoot toad (Spea 

intermontana) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-4-9, Habitat 

Section-Riparian p. III-8-14 to 8-18, Foothill Shrublands p. III-4-10 to 4-12, 

Wetlands p. III-10-11 to 10-13 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

Place water development s and salt and mineral supplements for livestock at least 

500 feet from known or potential locations of this plant species (Casper FO RMP 

2007) 

Improve floodplain connectivity and function of stream miles (Casper FO RMP 

2007). 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Fish: Colorado River cutthroat 

trout (Oncorhynchus clarkii 

pleuriticus), roundtail chub (Gila 

robusta), flannelmouth sucker 

(Catostomus latipinnis), and 

bluehead sucker (Catostomus 

discobolus) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts p. IV-3-19, p. IV-3-

68, p. IV-3-28 and p. IV-3-3; III-13-17 thru 13-19; Aquatic Basins p. III-13-17 to 13-

19, Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

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APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2b. Summary of references for wildlife protection measures, cause and effect studies, and 

adaptive management requirements: wildlife and associated habitats, continued 

Species / Habitat Protection Measures, Cause and Effect Studies, and Adaptive Management 

Requirements 

Meadow milkvetch plant 

(Astragalus diversifolius var. 

diversifolius) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,15,17,18,24,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Place water development s and salt and mineral supplements for livestock at least 

500 feet from known or potential locations of this plant species (Casper FO RMP 

2007) 

Cedar Rim thistle plant (Cirsium 

aridum) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,15,17,18,24,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Habitat Section-Desert Shrublands p. 

III-3-8 to 3-10, Cliffs-Canyons-Caves and Rock Outcrops p. III-2-8 to 2-10 

Gibbens’ beardtongue plant 

(Penstemon gibbensii) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,15,17,18,24,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Habitat Section-Desert Shrublands p. 

III-3-8 to 3-10, Cliffs-Canyons-Caves and Rock Outcrops p. III-2-8 to 2-10 

Persistent sepal yellowcress 

plant (Rorippa calycina) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,15,17,18,24,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Aquatic Basins p. III-13-17 to 13-19, 

Habitat Section-Riparian p. III-8-14 to 8-18, Wetlands p. III-10-11 to 10-13 

Place water development s and salt and mineral supplements for livestock at least 

500 feet from known or potential locations of this plant species (Casper FO RMP 

2007) 

Big Game Crucial Winter Range, Migration Corridors, and Associated Habitats 

Big Game Crucial Winter Range BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,9,15,17,18,26 

and 36 

WGFD: BLM will request data from WGFD 

Habitat, Species: WGFD: Habitat Section Sagebrush Shrublands p. III-9-12 to 9-

15, Foothill Shrublands p. III-4-10 to 4-12, Desert Shrublands p. III-3-8 to 3-10 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Big Game Migration Corridors BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36; RFO Wildlife Attachment 

Habitat, Species: WGFD: Habitat Section Sagebrush Shrublands p. III-9-12 to 9-

15, Foothill Shrublands p. III-4-10 to 4-12, Desert Shrublands p. III-3-8 to 3-10 

BLM JIO-PAPO 2012. Pinedale Anticline Project Office, Bureau of Land 

Management, Pinedale Field Office. <http://www.wy.blm.gov/jiopapo/papo/index.htm> 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

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APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Table I-2b. Summary of references for wildlife protection measures, cause and effect studies, and 

adaptive management requirements: wildlife and associated habitats, continued 

Species / Habitat Protection Measures, Cause and Effect Studies, and Adaptive Management 

Requirements 

Raptors and Associated Habitats 

Raptors (Non-Special Status 

Species and BLM Sensitive 

Species) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-other bird species 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Songbirds, Waterfowl, and Shorebirds and Associated Habitats 

Songbirds, waterfowl, and 

shorebirds and associated 

habitats (Non-Special Status 

Species and BLM Sensitive 

Species) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-other bird species, Habitat Section-Riparian p. III-8-

14 to 8-18 – other species 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

Place water development s and salt and mineral supplements for livestock at least 

500 feet from known or potential locations of this plant species (Casper FO RMP 

2007) 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Amphibians, Reptiles, and Fish and Associated Habitats 

Amphibians, reptiles, and fish 

and associated habitats (NonSpecial Status Species and 

BLM Sensitive Species) 

BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 1,10,15,17,18,26 

and 36; RFO Wildlife Attachment 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-other amphibian, reptile and fish species; WY SWAP 

2010 Aquatic Basins p. III-13-17 to 13-19 – other fish species, Habitat SectionRiparian p. III-8-14 to 8-18 – other species 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

Place water development s and salt and mineral supplements for livestock at least 

500 feet from known or potential locations of this plant species (Casper FO RMP 

2007) 

Improve floodplain connectivity and function of stream miles (Casper FO RMP 

2007). 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

General Wildlife Species and Associated Habitats 

General Wildlife Species BLM 2008a Wildlife and Fisheries p. 2-51 to 2-55; Appendices 

1,10,14,15,17,18,26 and 36 

Habitat, Species: WGFD: WY SWAP 2010 Species Accounts, Species of 

Greatest Conservation Need-crustacean and mollusk species 

Develop water sources for wildlife in coordination with the WGFD and the BLM 

water Development Handbook {I-1741-0} (Casper FO RMP) 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas 

Resources within Important Wildlife Habitats. Version 6.0. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-31 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Literature Cited 

APLIC 1994. Mitigating Bird Collisions with Power Lines: The State of the Art in 1994. Avian Power 

Line Interaction Committee. Edison Electric Institute, Washington, D.C. 78 pp. + appendices. 

APLIC 1996. Suggested Practices for Raptor Protection on Power Lines: The State of the Art in 1996. 

Avian Power Line Interaction Committee. Edison Electric Institute/Raptor Research Foundation, 

Washington, D.C. 125 pp. + appendices. 

AZGFD. 2009. Arizona Game and Fish Department Fish Survey Techniques. Online at 

<http://www.azgfd.gov/w_c/Fish_Survey_Techniques.shtml> 

Baxter, G.T., and M.D. Stone. 1980. Amphibians and Reptiles of Wyoming. Wyoming Game and Fish 

Department, Bulletin No. 16. 137 pp. 

BLM. 1985. Record of Decision for the Resource Management Plan/Final Environmental Impact 

Statement for Buffalo Resource Area (incorporating Rangeland Program Summary) Campbell, 

Johnson and Sheridan Counties, Wyoming Casper, Wyoming. October 1985. Online at 

<http://www.blm.gov/wy/st/en/field_offices/Buffalo/wildlife.html> 

BLM. 1997. Green River Resource Area Record of Decision and Green River Resource Management 

Plan. Rock Springs District Office. October 1997. Green River Resource Area. BLM/WY/PL97/027 + 1610. 

BLM. 2000. Record of Decision, Environmental Impact Statement, Continental Divide/Wamsutter II 

Natural Gas Project. Sweetwater and Carbon Counties, WY: BLM Rawlins and Rock Springs 

Field Offices. May 2000. 

BLM. 2007. Record of Decision and Approved Casper Resource Management Plan Updated with 

Amendments and Maintenance Actions. BLM/WY/PL-08/005+1610. December 2007. 

BLM. 2008a. Record of Decision and Approved Rawlins Resource Management Plan. BLM Rawlins 

Field Office. BLM/WY/PL-09/002+1610. December 2008. 

BLM. 2008b. BLM Manual 6840, Special Status Species Management. Online at 

<http://www.blm.gov/pgdata/etc/medialib/blm/wo/Information_Resources_Management/policy/b 

lm_manual.Par.43545.File.dat/6840.pdf> 

BLM. 2008c. Record of Decision and Approved Pinedale Resource Management Plan. Pinedale Field 

Office. Pinedale, Wyoming. BLM/WY/PL-09/014 + 1610. 

BLM. 2010. Bureau of Land Management High Desert District Wildlife and Plant Survey Protocols for 

Wind Energy Development. BLM High Desert District. p 17 and Appendix 1B (2010-003) 

BLM. 2011. Bighorn Basin Draft Resource Management Plan and Draft Environmental Impact 

Statement. Wind River/Bighorn Basin District. Cody and Worland Field Offices. Volume 3: 

Appendices, Glossary and Maps, Appendix L-2. 1610 (930). April 13, 2011. 

BLM JIO-PAPO. 2012. Pinedale Anticline Project Office, Bureau of Land Management, Pinedale Field 

Office. <http://www.wy.blm.gov/jio-papo/papo/index.htm> 

BLM Technical Note No. 316. U. S. Shorebird Conservation Plan: A Comprehensive Monitoring 

Program for North American Shorebirds. 2000. Pages 60-61, 80-81 

Call, M.W. 1978. Nesting Habitats and Surveying Techniques for Common Western Raptors. 

Cooperrider, A. Y., R. J. Boyd and H. R. Stuart, eds. 1986. Inventory/monitoring and Monitoring of 

Wildlife Habitat. U.S. Dept. Inter., Bur. Land Manage. Service Center. Denver, CO. xviii. 858 pp. 

BLM/YA/PT-87/001+6600 

I-32 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

Dorn, J.L., and R.D. Dorn. 1990. Wyoming Birds. Cheyenne, Wyoming: Mountain West Publishing. 138 

pp. 

Field Protocol for Spatially-Balanced Sampling of Landbird Populations. Hanni, D.J., C.M. White, R.A. 

Sparks, J.A. Blakesley, G.J. Levandoski, and J.J. Birek. 2010. Unpublished report. Rocky 

Mountain Bird Observatory, Brighton, CO. 34pp. 

Grier, J.W., and R.W. Fyfe. 1987. “Preventing Research and Management Disturbance.” pages 173-182 

in B.A.G. Pendleton, B.A. Milsap, K.W. Cline, and D.M. Bird, editors. Raptor Management 

Techniques. Institute of Wildlife Research, National Wildlife Federation, Scientific and Technical 

Series No. 10. 420 pp. 

Ministry of Environment, Lands and Parks. 1998. Species Inventory/monitoring Fundamentals Standards 

for Components of British Columbia’s Biodiversity No. 1. Prepared by Ministry of Environment, 

Lands and Parks, Resources Inventory/monitoring Branch for Terrestrial Ecosystems Task Force 

Resources Inventory/monitoring Committee. November, 1998. Version 2.0 

Olendorff, R.R., A.D. Miller, and R.M. Lehman 1981. Suggested Practices for Raptor Protection on 

Power Lines: The State of the Art in 1981. 

Naugle, David E. 2011. Energy Development and Wildlife Conservation In Western North America. 

Raptor Research Report No. 4. St. Paul, MN: Raptor Research Foundation, Inc., University of Minnesota. 

111 pp. 

Taylor, J. Christopher and Suzanne L. Maxwell. 2007. Hydroacoustics: Lakes and Reservoirs. Online at 

<http://www.stateofthesalmon.org/fieldprotocols/downloads/SFPH_p5.pdf> 

The Nature Conservancy in Wyoming. 2012. 258 Main Street, Suite 200, Lander, Wyoming 82520. 

307.332.2971. Online at Wyoming@tnc.org or 

<http://www.nature.org/wherewework/northamerica/states/wyoming/> 

USFWS 1989. Black-footed Ferret Survey Guidelines for Compliance with the Endangered Species Act. 

Denver, Colorado, and Albuquerque, New Mexico: U.S. Fish and Wildlife Service. April 1989. 

10 pp. + appendices. 

USFWS 2011. Trumpeter Swan Survey of the Rocky Mountain Population Winter 2011. U.S. Fish and 

Wildlife Service Migratory Birds and State Programs Mountain-Prairie Region Lakewood, 

Colorado. April 12, 2011. Online at 

<http://www.fws.gov/mountainprairie/species/birds/trumpeterswan/trumpeter_swan_survey_wint 

er_2011.pdf> 

USFWS Red Rock Lakes National Wildlife Refuge. Mountain-Prairie Region. March 1, 2011. 

<http://www.fws.gov/redrocks/Refuge-Management-Trumpeter-Swan.htm> 

U. S. Shorebird Conservation Plan: A Comprehensive Monitoring Program for North American 

Shorebirds. 2000. Pages 60-61, 80-81 

Wetlands Regional Monitoring Program Plan 2002, Part 2: Data Collection Protocols Shorebirds, Gary 

W. Page, Point Reyes Bird Observatory, Stinson Beach CA and Nils Warnock, Point Reyes Bird 

Observatory, Stinson Beach CA. 

Wildlife Landscape Conservation Initiative. 280 Highway 191 N., Rock Springs, Wyoming 82901. 

307.352.0397. wlci_wymail@blm.gov 

WGFD. 1992. Wyoming Bird and Mammal Atlas. Wyoming Game and Fish Department. 170 pp. 

WGFD. 1996. Wyoming Observation System Records. Cheyenne, Wyoming: Wyoming Game and Fish 

Department, Biological Services. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 I-33 
APPENDIX I—WILDLIFE MITIGATION, MONITORING, AND PROTECTION PLAN 

WGFD. 1997. Atlas of Birds, Mammals, Reptiles and Amphibians in Wyoming. Lander, Wyoming: 

Wyoming Game and Fish Department, Wildlife Division, Biological Services Station, Nongame 

Program. 192 pp. 

WGFD. Revised April 2010. Recommendations for Development of Oil and Gas Resources within 

Important Wildlife Habitats. Version 6.0. Wyoming Game and Fish Department, Cheyenne, 

Wyoming. 

<http://gf.state.wy.us/downloads/doc/OandG%20Recommendations%20April%202010%20with 

%20changes%20identified.pdf> 

WGFD. 2010. Wildlife Protection Recommendations for Wind Energy Development in Wyoming. 

Wyoming Game and Fish Department, Cheyenne, Wyoming. Online at 

<http://gf.state.wy.us/downloads/pdf/April%2023%202010%20Commission%20Approved%20W 

ind%20Recommendations.pdf> 

WGFD. 2010. State Wildlife Action Plan. Wyoming Game and Fish Department, 5400 Bishop Blvd., 

Cheyenne, WY 82006. Contact: 307-777-4637, glenn.pauley@wgf.state.wy.us or 

<http://gf.state.wy.us/swap2010/index.asp> 

WYNDD 1995. Wyoming Vertebrate Species of Concern List. Compiled by C. Garber for the Nature 

Conservancy, Wyoming Natural Diversity Database. 21 pp. + appendices 

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APPENDIX J: CULTURAL RESOURCES MANAGEMENT 

Table of Contents 

Program Objectives ................................................................................................................. J-1 

Identification of Cultural Resources ...................................................................................... J-1 

BLM Jurisdiction on Privately Owned and/or Split-Estate Lands (including the 

checkerboard land pattern) ........................................................................................................ J-2 

Survey .................................................................................................................................................. J-2 

Site Management................................................................................................................................. J-3 

Evaluation of Cultural Resource Sites ................................................................................................. J-3 

BLM Use Allocations.......................................................................................................................... J-4 

Determinations of Effect ..................................................................................................................... J-5 

Consultation ....................................................................................................................................... J-6 

Management of Cultural Resources .................................................................................................... J-7 

Mitigation .......................................................................................................................................... J-8 

Cultural Resource Laws and Regulations............................................................................................ J-9 

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APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

PROGRAM OBJECTIVES 

The Bureau of Land Management (BLM) has developed a cultural resources program designed to 

inventory, evaluate, and manage cultural resources on BLM-administered public land and in areas of 

BLM responsibility. The BLM management of cultural resources (archaeological, historic, and sociocultural properties) is in accordance with the provisions of the National Historic Preservation Act (NHPA) 

of 1966, as amended, and other applicable legislation. 

IDENTIFICATION OF CULTURAL RESOURCES 

The BLM requires cultural resource inventories for actions with federal responsibility that include surface 

disturbance as a part of the action. The purpose of inventories is to identify cultural resources prior to any 

ground-disturbing activity. This way, sites can be protected through project redesign or other mitigation 

measures prior to any threat of disturbance. Numerous laws and regulations mandate this policy. For a 

brief overview of selected laws and policies dictating BLM’s treatment of cultural resources, please see 

the end of this appendix. 

Three classes of cultural resource inventory have been established; Class III is the most intensive. 

Class I inventories are completed with the use of existing data from cultural resource inventory files 

maintained by both the BLM and the Wyoming State Historic Preservation Office (SHPO). Class I 

inventories are conducted at two different levels: at the planning stage of an environmental impact 

statement (EIS) to produce a regional overview; and at the site-specific level for individual proposed 

projects to determine if previous cultural resource inventories have been conducted within the area of 

potential effect (APE). The purpose of Class I inventories is to provide cultural resource specialists and 

managers with an informed basis for understanding the nature of the archaeological record within the area 

in question. 

Class II inventories are statistically-based sample surveys designed to aid in characterizing the probable 

density, diversity, and distribution of cultural properties in the area, to develop and test predictive models, 

and to answer appropriate research questions. Within individual sample units, survey aims, methods, and 

intensity are the same as those applied in a Class III survey. Class II surveys may be conducted in several 

phases, using different sample designs, to improve statistical reliability. 

Class III intensive field surveys are conducted by professionals through pedestrian survey of an entire 

target area. The intent of a Class III inventory is to locate and record all historic properties and is 

consistent with standards in the Secretary of the Interior's Standards and Guidelines for Archaeology and 

Historic Preservation (48 FR 44716). Class III inventories conform to the prevailing professional survey 

standards for the region involved, provided that the regional standards meet or exceed the Secretary's 

Standards and Guidelines. Because a Class III survey is designed to produce a total inventory of the 

cultural properties observable within the target area, once it has been completed, no further survey work 

should be needed in the target area as long as the current standards are met. Areas with a high probability 

of containing buried cultural materials or known cultural materials may require additional work or 

professional monitoring and/or data recovery excavations. Areas that require additional work are analyzed 

on a case-by-case basis, depending on the proposed action and the types of cultural resources present in 

the project area. 

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APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

BLM JURISDICTION ON PRIVATELY OWNED AND/OR SPLIT-ESTATE LANDS 

(including the checkerboard land pattern) 

Survey 

The BLM frequently authorizes permits and rights-of-way, or provides approvals for actions on federal 

lands in which portions of the overall project may take place on non-federal lands or the federal action 

may have contingent or cumulative effects on non-federal lands. Before the BLM can authorize (through 

permit, license, etc.) any project that may adversely affect significant cultural resources (i.e., historic 

properties), the BLM has the legal responsibility to take into account the effects of its actions on these 

resources. In order for the BLM to fully consider the effects of its actions, it also has the responsibility to 

gather the information necessary to know what cultural resources may be affected, evaluate the resources 

for eligibility for inclusion in the National Register of Historic Places, and mitigate adverse affects to 

historic properties where possible. 

If a project requires the use of federally-owned surface lands as well as privately owned surface lands, 

there are two authorities that require federal agencies to apply the same NHPA Section 106 compliance 

standards to private lands as they do to federal lands. The regulations at 36 CFR, Part 800.4(b) require the 

federal agency to "take the steps necessary to identify historic properties within the area of potential 

effect." That this includes both federal and non-federal lands is implicit throughout the statute and the 

regulations, since the regulatory definition of "area of potential effect" is "the geographic area or areas 

within which an undertaking may directly or indirectly cause changes in the character or use of historic 

properties" [36 CFR, Part 800.16(d)]. It makes no distinction between federal and non-federal lands. 

More explicit, however, is Executive Order No. 11593, entitled "Protection and Enhancement of the 

Cultural Environment." Section 1(3) of the EO states that all federal agencies: " ... in consultation with the 

Advisory Council on Historic Preservation, institute procedures to assure that federal plans and programs 

contribute to the preservation and enhancement of non-federally owned sites, structures and objects of 

historical, architectural, or archaeological significance." The BLM's responsibility for inventory, 

evaluation, and protection of cultural properties on lands outside BLM administrative jurisdiction is 

limited according to the degree to which the Field Manager's decisions determine or control the location 

of surface-disturbing activities on those lands. 

BLM makes this policy known to project proponents, who in turn are responsible for providing all of the 

information the BLM requires for making informed decisions. If cultural resource data is lacking from 

private lands so that the BLM authorized officer cannot make an informed decision, the BLM cannot 

allow the undertaking to proceed. Thus, it is the responsibility of the project proponent to acquire the 

appropriate information. 

Within the checkerboard land pattern that encompasses much of the planning area, Wyoming BLM has 

set forth the policy that the entire project area, if it covers any federal lands, must be inventoried. The 

reasoning for this is that the distances between federal ownership and private ownership are so short, that 

the potential for the federal portion to not dictate the placement of the project on private is remote. 

Split estate lands are defined as those lands where surface ownership transferred to private landowners 

from the federal government but the mineral rights were retained by the federal government. These 

situations arose either through patent under the 1914 amendment to the Homestead Act or purchase under 

the Stock-raising Act of 1916. Each of these Acts also allowed for the federal government to "reenter and 

occupy so much of the surface ... as may be required for all purposes reasonably incident to the mining or 

removal of coal or other minerals." At the time of purchase, the buyer agreed to these terms. Since 

compliance with the NHPA Section 106 process is required of a federal agency by statute and regulation 

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APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

prior to the federal action, then being able to complete that process is a purpose reasonably incident to the 

extraction of the minerals. 

Site Management 

As stated above, BLM has multiple authorities for requiring cultural resource inventories on private lands. 

This jurisdiction only holds forth with federal undertakings. Cultural resources that are located on private 

lands are recorded for the permanent record and appropriate mitigation measures are applied, in 

consultation with the private landowner. This jurisdiction comes from the requirement that the federal 

agency must take into account its effects on all historic properties. Once the federal undertaking has been 

fully processed, the federal responsibility for an historic property is completed. The historic property 

remains under the ownership of the landowner, thus BLM has no control over the historic property 

outside of the venue of a federal undertaking. 

Evaluation of Cultural Resource Sites 

Criterion for Eligibility 

The BLM evaluates the significance of cultural resources identified during inventory in consultation with 

the Wyoming SHPO to determine if the resources are eligible for inclusion in the National Register of 

Historic Places (NRHP). Cultural resource properties may be considered eligible for listing in the 

National Register if they meet one or more of the following criteria identified in 36 CFR 60.4: 

	 Criterion A. An historic property is associated with an event or events that have made a significant 

contribution to the broad patterns of America's history. 

	 Criterion B. An historic property is associated with the lives of persons significant to our past. 

	 Criterion C. An historic property embodies the distinctive characteristics of a type, period, or method 

of construction, or represents the work of a master, or possesses high artistic value or represents a 

significant and distinguishable entity whose components may lack individual distinction. 

	 Criterion D. An historic property has yielded or may be likely to yield information important in 

prehistory or history.
 

To facilitate evaluation of cultural resource values in Wyoming, the BLM has devised guidelines for 

determining the eligibility of archaeological and historical sites and historic trails (BLM Manual 

8110.32). The guidelines supplement the National Register criteria for evaluation (36 CFR 60.4) and 

provide consistency across all BLM jurisdictions. Application of the guidelines ensures that significant 

cultural resources are recognized and managed accordingly. 

Aspects of Integrity 

Integrity is the ability of a property to convey its significance. To be listed in the National Register of 

Historic Places, a property must not only be shown to be significant under the National Register criteria, 

but it also must have integrity. The evaluation of integrity is sometimes a subjective judgment, but it must 

always be grounded in an understanding of a property's physical features and how they relate to its 

significance. 

Historic properties either retain integrity (this is, convey their significance) or they do not. Within the 

concept of integrity, the National Register criteria recognizes seven aspects or qualities that, in various 

combinations, define integrity. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 J-3 
 

 

 

 

APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

To retain historic integrity a property will always possess several, and usually most, of the aspects. The 

retention of specific aspects of integrity is paramount for a property to convey its significance. 

Determining which of these aspects are most important to a particular property requires knowing why, 

where, and when the property is significant. 

 Location. The place where the historic property was constructed or the place where the historic event 

occurred. 

 Design. The combination of elements that create the form, plan, space, structure, and style of a 

property. 

 Setting. The physical environment of an historic property. 

 Materials. The physical elements that were combined or deposited during a particular period of time 

and in a particular pattern or configuration to form an historic property. 

 Workmanship. The physical evidence of the crafts of a particular culture or people during any given 

period in history or prehistory. 

 Feeling. The property's expression of the aesthetic or historic sense of a particular period of time. 

 Association. The direct link between an important historic event or person and an historic property. 

Contributing and Non-Contributing to NRHP Eligibility 

Properties that encompass large areas can be deemed to have contributing and noncontributing portions. 

Contributing portions are seen to retain integrity of the values for which the property is considered 

eligible for the NRHP. Non-contributing portions are identified portions of the property which are not 

deemed to retain the integrity of values which would render the property eligible for the NRHP. The 

determination of contributing versus noncontributing portions of an eligible property can be made at any 

time after adequate evaluation has been conducted. 

Historic trails including the Overland and Cherokee, the Rawlins to Fort Washakie Freight Road, and the 

Rawlins to Baggs Freight Road, are considered eligible for the National Register under Criterion A. 

However, some portions of the trails no longer retain the aspects of integrity necessary for eligibility. As 

there have been no encompassing inventories of entire trails within the Resource Management Plan 

Planning Area (RMPPA), portions of trails are evaluated to determine if they contribute to the eligibility 

of the property on a case-by-case basis. Trail segments are evaluated pursuant to the National Register 

criteria of integrity (location, design, setting, materials, workmanship, feeling, and association). If a 

predominance of criteria are met, the segment will be considered contributing to the properties' overall 

NRHP eligibility. 

BLM Use Allocations 

After determination of eligibility, significant cultural resource properties are further evaluated for assignment 

to one or more use categories. The BLM has established six use categories as follows: 

	 Scientific Use. This category applies to any cultural property determined to be available for scientific 

or historical study using currently available research techniques, including methods that would result 

in the property's physical alteration or destruction. Recommendations to allocate individual properties 

to this use must be based on documentation of the kinds of data the property is thought to contain and 

the data's importance for pursuing specified research topics. 

	 Conservation for Future Use. A cultural property included in this category is deemed worthy of 

segregation from all other land or resource uses, including cultural resource uses, which threaten the 

maintenance of its present condition or setting, and will remain in this use category until specified 

provisions are met in the future. 

J-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

	 Traditional Use. This category is to be applied to any cultural resource known to be perceived by a 

specified social and/or cultural group as important in maintaining the cultural identity, heritage, or 

well being of the group. Cultural properties assigned to this category are to be managed in ways that 

recognize the importance ascribed to them and seek to accommodate their continuing traditional use. 

	 Public Use. This category may be applied to a cultural property found to be appropriate for use as an 

interpretive exhibit in place, or for related educational and recreational uses by members of the 

general public. 

	 Experimental Use. This category may be applied to a cultural property judged well suited for 

controlled experimental study, to be conducted by BLM or others, concerned with the techniques of 

managing cultural properties, which would result in the property's alteration, possibly including loss 

of integrity and destruction of physical elements. It should not be applied to cultural properties with 

strong research potential, traditional cultural importance, or good public use potential, if it would 

significantly diminish those uses. 

	 Discharged from Management. This category is assigned to cultural properties that have no remaining, 

identifiable use. Most often these are prehistoric and historic archaeological properties, such as small 

surface scatters of artifacts or debris, whose limited research potential is effectively exhausted as soon 

as they have been documented. Properties discharged from management remain in the inventory, but 

they are removed from further management attention and do not constrain other land uses. 

When a cultural resource property is assigned to one or more use categories, a decision is made pertaining to 

the management of that property. The criteria and guidelines for the evaluation of cultural resources and the 

assignment of significant cultural resource properties to specific use categories would remain unchanged under 

all the alternatives addressed in this plan. 

Determinations of Effect 

Once the eligibility of an historic property has been determined, the BLM must then determine the effects 

a proposed undertaking may have on a cultural resource. Standard measures for reducing effects are to be 

considered part of the project design. Determination of effect must be made after standard treatment 

measures and best management practices (BMP) have been integrated into the project design. The final 

project design must incorporate all agreed upon treatment measures and be included in the Conditions of 

Approval or components of the Surface Use Plan, Plan of Operations, or Plan of Development. 

No Historic Properties Affected. If no cultural resource sites eligible for listing in the NRHP are present 

in the proposed project area, there are historic properties present but the undertaking will have no effect 

upon them, or a proposed project will not be visible from an historic property or there is no contrast 

between the project and the setting, the BLM will find that the undertaking has no potential to affect 

historic properties. 

No Historic Properties Adversely Affected. If a proposed project will cause effects to an historic 

property, but the effects will not diminish the aspects of integrity nor the characteristics that make the 

property eligible for listing in the National Register of Historic Places, only noncontributing portions of 

historic properties will be affected, or if setting is an important aspect of integrity for an historic property 

and the project will cause a weak contrast, the BLM will find that the undertaking has no potential to 

adversely affect historic properties. 

Historic Properties Adversely Affected. An adverse effect is found when an undertaking may alter, 

directly, or indirectly, any of the characteristics of an historic property that qualify the property for 

inclusion in the National Register in a manner that would diminish the integrity of the property's location, 

design, setting, materials, workmanship, feeling, or association. Consideration shall be given to all 

qualifying characteristics of an historic property, including those that may have been identified 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 J-5 
APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

subsequent to the original evaluation of the property's eligibility for the National Register. Adverse effects 

may include reasonably foreseeable effects caused by the undertaking that may occur later in time, be 

farther removed in distance, or be cumulative. 

Consultation 

SHPO Consultation 

According to the Programmatic Agreement between the Advisory Council on Historic Preservation 

(ACHP) and the BLM, the BLM is required to consult with the Wyoming SHPO on eligibility and effects 

to each cultural property. The Wyoming BLM and Wyoming SHPO have developed a Protocol for 

consultation that serves to streamline the process and reduce consultation time frames from the guidelines 

set forth in the 36 CFR 800 regulations. Under the Protocol between the Wyoming BLM and the 

Wyoming SHPO, those sites recommended as Eligible for listing under Criteria A, B, or C or the setting 

is an important aspect of integrity requiring case-by-case consultation with the Wyoming SHPO. 

Additionally, the BLM has implied concurrence for determining eligibility and effects for sites eligible 

for listing under Criterion D of the NHPA. Determination of effects to sites follows the criteria outlined in 

36 CFR 800.5. 

Native American Consultation 

In addition to consultation with the Wyoming SHPO office, the BLM conducts Native American 

Consultation in compliance with Section 106 of the NHPA, the American Indian Religious Freedom Act 

of 1978, and Executive Order No. 13007. The BLM has created a process for conducting Native 

American consultation for federal undertakings, as described in BLM Manual 8120 and BLM Manual H8120-1. The BLM has worked extensively with tribes known to inhabit the region to establish a protocol 

for consultation. Consultation with Native American tribes occurs during the planning process of 

environmental impact statements and when individual projects are proposed that may impact properties 

that have traditional use (i.e., Traditional Cultural Properties [TCPs]) or are sacred to Native American 

cultures. When one of these site types is identified within proximity to a proposed undertaking, the project 

proponent and tribal governments are notified. Determinations of eligibility and effects the project may 

have on the site are determined in consultation with tribal representatives. The BLM does not authorize 

any undertaking that has the potential to affect TCPs or Native American Sacred Sites without first 

consulting with tribes. The likelihood of inadvertently affecting a TCP or sacred site is low because of the 

established protocols BLM has developed with tribal representatives. 

Interested Parties 

The BLM will solicit such input through the public participation opportunities afforded by BLM's land 

use planning and environmental review processes established under the National Environmental Policy 

Act (NEPA) of 1969 and the Federal Land Policy and Management Act (FLPMA) of 1976, and in 

accordance with regulations at 43 CFR Part 1610.3. Interested parties shall be invited to participate in the 

Section 106 consultation process if they have a demonstrated interest in a BLM undertaking or action on 

historic properties. Such interested parties may include, but are not limited to, local governments, 

grantees, permittees, owners of affected lands or land surfaces, Indian tribes, and other interested parties 

determined jointly by BLM and SHPO. 

In making determinations of effect, BLM may request comments of interested parties. When BLM makes 

a determination of adverse effect, they will request comments of interested parties. BLM will maintain 

lists of interested parties based on their identified interests. 

J-6 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

BLM and SHPO will consult to identify invited concurring parties based on their demonstrated interest 

and level of participation. Invited concurring parties will be provided the opportunity to sign a 

Memorandum of Agreement or Programmatic Agreement. Refusal by an invited concurring party to sign 

an agreement will not invalidate the agreement. 

Management of Cultural Resources 

Management objectives for significant cultural resource values provide a direct link between the 

assignment of properties to use categories and the achievement of the cultural resource program 

objectives. The basic management objectives for significant cultural resource values would remain 

unchanged under all of the alternatives addressed in this plan. 

Specific management actions that could be taken to achieve these objectives at selected significant 

properties are described in the discussions of the various alternatives. Management objectives for 

significant properties that have not yet been identified or for which inventory data are insufficient as of 

this writing will remain unchanged, but management actions for these properties will be prescribed on a 

case-by-case basis and will be addressed in amendments to this plan when appropriate. 

Standard Protective Measures 

Within the framework described above, the BLM has developed protective measures to minimize adverse 

effects (as defined in 36 CFR 800.5[1]) on significant cultural resource values. Protective measures are 

used in response to the proposed actions of BLM programs involving surface disturbance. These 

measures include cultural resource inventories, evaluation of cultural resources located during inventory, 

setting assessments where applicable, best management practices and mitigation of potential adverse 

impacts on significant cultural resources. 

A setting assessment is used to determine what physical features of a proposed undertaking will be visible 

from an historic property for which setting is an important aspect of integrity. Visibility of undertakings 

will vary. The scale of visual analysis should be commensurate with the scale of the undertaking. In the 

majority of cases, undertakings will not be seen beyond three miles; pipelines, fiber-optic and other 

ground level disturbance will not likely be seen beyond a mile. In rare cases, undertakings may be seen 

beyond five miles if they are unusually large or are skylined on the horizon, such as wind turbines and 

communication towers. 

A setting assessment can also be used to determine whether a proposed undertaking will introduce audible 

elements to the historic property where setting is an important aspect of integrity. These proposed 

undertakings may include compressor stations, pumping stations, or wind turbines. An assessment of the 

existing audible elements will be documented and then the BLM archaeologist will work with the project 

proponent to ensure new audible elements do not result in an adverse effect. Best management practices 

and mitigation measures will be utilized to achieve this goal. 

Best Management Practices 

In situations where a proposed undertaking has the potential to affect the physical integrity of an historic 

property, there are numerous measures that can be applied to reduce or eliminate the effects. BLM 

archaeologists work with the contracting archaeologist and the project proponent to determine which 

practice would best suit the needs of all parties. Application of BMPs is dependent upon the nature of the 

undertaking, and the nature of the historic property. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 J-7 
APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

Avoidance. Avoidance, through modification of the proposed undertaking, is the primary and preferred 

measure used to protect cultural resources. This can be accomplished at the project planning stage. 

Monitoring. In situations where avoidance of adverse affects is not feasible, or there is a determination of 

no adverse effects, but the potential remains for adverse effects through inadvertent discovery, a BLM 

permitted archaeologist will monitor construction activities. The presence of a monitor is to ensure that 

buried cultural materials are immediately identified and that construction activities in that area are halted 

to avoid further impacts to the site. Prior to BLM authorization of the project, the project proponent 

submits a discovery plan to the BLM for review which outlines the way in which cultural resources will 

be treated and the responsibilities of the project proponent. This plan is reviewed by BLM archaeologists 

and submitted to SHPO for concurrence. In the case where monitoring results in a discovery situation, the 

discovery plan is enacted. Depending on the nature of the discovery the project may be allowed to 

proceed, redesigned, or data recovery may be required. 

Standard Measures to Reduce Visual Contrast. When a proposed project is found to be within the 

contributing setting of an historic property, an assessment of potential impacts is conducted through 

viewshed analysis, on-site inspection, and photo inspection. For historic trails such as the Cherokee Trail, 

Overland Trail, Rawlins to Fort Washakie Road and Rawlins to Baggs Road, protection measures would 

be carried out similar to other historic properties if any project were found to be located within a quarter 

mile of a contributing portion of the historic trail. When a proposed project is outside of the quarter mile 

buffer of the trail, but found to be within the viewshed that contributes to NRHP eligibility, analyses of 

potential impacts to the integrity of the setting would be carried out in the same way as other properties 

where setting is an aspect of integrity. Best management practices used to ensure that the contributing 

viewshed of historic properties are not adversely affected include: 

 Consolidating project facilities among oil and gas developers—this also facilitates cumulative 

analysis. 

 Developing coordinated road and pipeline systems. 

 Reducing the amount of surface development by consolidating facilities (e.g., develop bottom hole 

wells using directional drilling from a single surface well location). 

 Using low profile facilities. 

 Proper sighting and location to maximize the use of topography and vegetation to screen 

development. Design projects to blend with topographic forms and existing vegetation patterns. 

 Using environmental coloration or advance camouflage techniques to break up visual intrusion of 

facilities that cannot be completely hidden. 

 Using broken linear patterns for road developments to screen roads as much as possible. This can 

include feathering or blending of the edges of linear rights-of-way to break up the linearity. 

 For livestock control, using electric fencing with low-visibility fiberglass posts and environmental 

colors (e.g., sage green). 

 Designing linear facilities and seismic lines to run parallel to key observation points rather than 

perpendicular. 

 Modifying the orientation of facilities to present less of a visual impact (e.g., a facility with several 

tanks lined up so that one obscures the visibility of the others). 

Mitigation 

Mitigation measures are determined by the types of proposed actions, the nature of the potential effect 

and the qualities of the historic property that render it eligible for NRHP listing. Mitigation measures are 

applied when best management practices will not reduce or minimize adverse effects. Mitigation may 

include data recovery. Consultation with the Wyoming SHPO and the ACHP is required when proposed 

J-8 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

actions are expected to adversely affect properties eligible for the National Register and mitigation is 

determined to be the best course of action. 

Data Recovery. There are two times during a project that data recovery may be implemented. The first is 

when it is determined prior to project construction that there will be an adverse effect to an NRHP eligible 

property. The project proponent, the BLM, and the SHPO work together to develop a data recovery plan 

which will mitigate the adverse effects. The second is after a discovery situation when it is determined 

that the project has already adversely impacted an historic property. Again, the project proponent, BLM 

authorized officer, and SHPO work to develop a plan that mitigates all effects of the construction. Data 

recovery in itself is a destructive process, thus it must be carried out in a way to successfully retrieve all 

pertinent information from the site. 

HABS/HAER (Historic American Buildings Survey/Historic American Engineering Record). 

HABS/HAER documentation as a mitigation measure may be implemented if no other mitigation 

measure would adequately minimize the adverse effect. This documentation includes large format 

photography, drawings, and research of the property to document all aspects of the property prior to 

adverse effects. 

Agreement Documents. In situations where data recovery or HABS/HAER documentation is not 

appropriate to mitigate adverse effects or multiple historic properties will be affected by a single 

undertaking, the BLM will work with the SHPO and the project proponent to develop an agreement 

document. Depending on the nature of the undertaking, this may result in a Memorandum of Agreement 

(MOA) or a Programmatic Agreement (PA). The agreement document will outline the manner in which 

adverse effects will be mitigated, and the roles and responsibilities of each signatory. The agreement 

document stays in effect until all measures have been completed to the satisfaction of all parties. 

Cultural Resource Laws and Regulations 

American Antiquities Act of 1906 provides for permits to authorize scholarly use of properties, for 

misdemeanor-level penalties to control unauthorized use, and for presidential designation of outstanding 

properties as national monuments for long-term preservation. 

National Historic Preservation Act of 1966 

 Section 106 directs all federal agencies to take into account effects of their undertakings (actions and 

authorizations) on properties included in or eligible for the NRHP. 

 Section 110 sets inventory, nomination, protection, and preservation responsibilities for federally 

owned cultural properties. Section 110 (c) requires each federal agency to designate a Preservation 

Officer to coordinate activities under the act. 

American Indian Religious Freedom Act of 1978 establishes the policy of the United States to protect and 

preserve for the American Indian, Eskimo, Aleut, and Native Hawaiian the inherent right of freedom to 

believe, express, and exercise their traditional religions. Federal agencies are directed to evaluate their policies 

and procedures to determine if changes are needed to ensure that such rights and freedoms are not disrupted by 

agency practices. 

Archaeological Resources Protection Act of 1979 provides felony-level penalties for the unauthorized 

excavation, removal, damage, alteration, defacement, or the attempted unauthorized removal, damage, 

alteration, or defacement of any archaeological resource, more than 100 years of age, found on public lands or 

Indian lands. The act also prohibits the sale, purchase, exchange, transportation, receipt, or offering of any 

archaeological resource obtained from public lands or Indian lands. 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 J-9 
APPENDIX J—CULTURAL RESOURCE MANAGEMENT
 

Native American Graves Protection and Repatriation Act of 1990 requires Native American consultation 

for the excavation and/or removal of "cultural items" including human remains, funerary objects, sacred 

objects, and objects of cultural patrimony. Consultation is also required if "cultural items" are discovered 

during land use activities. 

Executive Order No. 13007: Indian Sacred Sites establishes access to and ceremonial use of Indian sacred 

sites by Indian religious practitioners on federal lands. The federal agencies shall avoid adversely affecting the 

physical integrity of such sacred sites and maintain confidentiality of said sites. 

J-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K: HAZARDOUS MATERIALS MANAGEMENT SUMMARY 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

409 

Monoethanolamine

n-Alkyl (C12-16) Dimethylbenzyl 

Ammonium Chloride 

n-Propoxypropanol

 141-43-5 

68424-85-1 

 1569-01-3 

Acfrac Ceramax E 

Crystalline Silica, Quartz 

Mullite

Phenol/Formaldehyde resin 

14808-60-7 

 1302-93-8 

9003-35-4 

Adhesive, Polyguard 600 

Liquid 

Methyl Ethyl Ketone 

Mineral Spirits 

Toluene

78-93-3 

64742-88-7 

 108-88-3 

U159 

U109 

5,000 

10 

Ajax, Oxygen Bleach Cleaner Calcium Carbonate 

Crystalline Silica 

471-34-1 

14808-60-7 

Amoco 300 Motor Oil 

SAE 30 MSDS Not Found None 

Antifreeze 60/40 premix Ethylene Glycol 

Diethylene Glycol 

107-21-1 

111-46-6 

None 5,000 

AntiSeize Special Lubricating 

Compound 18014 

Aluminum (as dust or fume) 

Copper (as dust or fume) 

Graphite

Petroleum Oil 

7429-90-5 

7440-50-8 

 7782-42-5 

64742-65-0 

None 5,000 

BA-20 Buffering Agent Acetic Acid 

Ammonium Acetate 

64-19-7 

631-61-8 

None 

None 

5,000 

5,000 

BA-40L Buffering Agent Potassium Carbonate 584-08-7 

Barite Barium Sulfate 

Crystalline Silica, Quartz 

7727-43-7 

14808-60-7 

Barite (Barium Sulfate, 

MI Bar) MSDS Not Found None 

Base, Belzone 1221 

Super-E Metal MSDS Not Found None 

Battery Cleaner #80369 

2-Butoxyethanol

Butane

Propane

Water 

 111-76-2 

 106-97-8 

 74-98-6 

7732-18-5 

BC-140 

Boric Acid 

Ethylene Glycol 

Monoethanolamine

10043-35-3 

107-21-1 

 141-43-5 

None 5,000 

BE-5 Microbiocide 

2-Methyl-4-Isothiazoline-3-one 

5-Chloro-2-Methyl-4-Isothiazolin-3-one

Crystalline Silica, Quartz 

Diatomaceous Earth 

Magnesium Chloride 

Magnesium Nitrate 

2-Bromo-2-nitro-1,3-propanediol

2682-20-4 

 26172-55-4 

14808-60-7 

61790-53-2 

7786-30-3 

10377-60-3 

 52-51-7 

Big D Deodorant Urinal 

Screens MSDS Not Found None 

Bleach Sodium hydroxide 

 Sodium hypochlorite 

1310-73-2 

7681-52-9 

None 

None 

1,000

100 

Boothill Paraffinized Pellets Bromadiolone 28772-56-7 

Borax Powdered Hand Soap Sodium Borate Decahydrate (Borax) 

Sodium Soap 

1303-96-4 

67701-11-5 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-1 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Bowl Cleaner, #2300 

Hydrogen Chloride 

Quaternary Ammonium Chloride 

Water 

7647-01-0 

111-76-2 

7732-18-5 

None 5,000 

Brake Parts Cleaner II, Misty 

A-00734 

Acetone

Hexane

 67-64-1 

 110-54-3 

U002 5,000 

Breakthrough (Washbay 

Pressure Washer Soap) MSDS Not Found None 

C9721A Toner 

Copper Compund 

Styrene Acrylate Copolymer 

Wax 

Trade Secret 

Trade Secret 

Trade Secret 

Calcium Chloride Calcium Chloride 010043-52-4 

Calcium Chloride Solution Calcium Chloride 010043-52-4 

Cal-Seal 60 Calcium Sulfate None 

CarboHSP (Ceramic Proppant) Corundum

Mullite

 1302-74-5 

 1302-93-8 

Carbon Dioxide Carbon Dioxide 124-38-9 

CarboProp Corundum

Mullite

 1302-74-5 

 1302-93-8 

CAT-3 Activator EDTA/Copper Chelate None 

CAT-3WB EDTA/Copper Chelate 

Methanol

None 

 67-56-1 U154 5,000 

CAT-4 Diethylenetriamine 111-40-0 

CAT-4 (Amine) MSDS Not Found None 

Caustic Soda (Sodium 

Hydroxide) Sodium hydroxide 1310-73-2 None 1,000 

Cedar Fiber (Shredded Cedar, 

Cellulose) MSDS Not Found None 

Cement- Class G Crystalline Silica, Quartz 

Portland Cement 

14808-60-7 

65997-15-1 

CFR-2 Red Label (Cement 

Friction Reducer) 

Polyvinylpyrrolidone

Sulfonated Organic Salt Condensate 

 9003-39-8 

None 

CFR-3 (Cement Friction 

Reducer) 

Sodium Formate 

Sulfonic Acid Salt 

141-53-7 

None 

Chevron Delco 400 SAE 30/40 

Motor Oil 

Highly Refined Mineral Oil 

Zinc Alkyl Dithiophosphate 

Mixture 

68649-42-3 

Chevron HDAX Low Ash Gas 

Engine Oil SAE 40 Highly Refined Mineral Oil Mixture 

Chevron Hydraulic Oil AW ISO 

32 Highly Refined Mineral Oil Mixture 

Chevron Rykon AW ISO 10 Highly Refined Mineral Oil Mixture 

Chevron SRI Grease NLG2 Highly Refined Mineral Oil Mixture 

CI-25 (Inhibitor- Acid) MSDS Not Found 

CL-11 Crosslinker Isopropanol

Titanium Complex 

 67-63-0 

None 

CL-22 Crosslinker 

Borate Salts 

Diesel

Methanol

None 

 68476-34-6 

 64-56-1 U154 5,000 

CL-22M Crosslinker Diesel 68476-34-6

 Ulexite 1319-33-1 

CL-23 Crosslinker Ammonium Chloride 12125-02-9 None 5,000 

CL-28M Crosslinker Zirconium Complex None 

K-2 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

CL-29 Crosslinker 

Formic Acid 

Lactic Acid 

Tetraethylenepentamine

Zirconium Complex 

64-18-6 

10326-41-7 

 112-57-2 

None 

U123 5,000 

CL-31 Crosslinker Potassium Hydroxide 

Potassium Metaborate 

1310-58-3 

13709-94-9 

None 1,000 

Cla-Sta XP Additive Polyepichlorohydrin, trimethyl amine 

quatemized 51838-31-4 

Clayfix-II Material Alkylated Quaternary Chloride None 

Cleaner/Degreaser, Belzona 

9111 MSDS Not Found None 

Compressed Gas, 25% 

Methane, 21% O2, N2 

Methane

Nitrogen

Oxygen

 74-82-8 

 7727-37-9 

 7782-44-7 

Condensate 

Mixture of aliphatic hydrocarbons of 

carbon number >=4 

Benzene

Hydrogen Sulfide 

Natural Gas 

n-Hexane

Mixture 

 71-43-2 

7783-06-4 

8006-14-2 

 110-54-3 

D-Air 3000L Alkenes 

Silica, amorphous precipitated 

None 

67762-90-7 

DAP Weldwood Contact 

Cement 

Aliphatic Petroleum Distillate 

Methyl Ethyl Ketone 

Toluene

64742-89-8 

78-93-3 

 108-88-3 

U159 

U109 

5,000 

10 

Dawn Monoethanolamine 141-43-5 

D-CON Ready Mixed Baits MSDS Not Found None 

Degreaser, Heavy Duty 

(Aerosol #03095) 

1,2-Butylene Oxide 

Carbon Dioxide 

Tetrachloroethylene (PERC) 

Trichloroethylene (TCE) 

106-88-7 

124-38-9 

127-18-4

79-01-6 

 U210

U228 

100 

100 

Delvac 1210 Motor Oil SAE 

10W 

Phosphorodithioic Acid, O, O-DI-C1-14-

Alkyl Esters, Zinc Salt (2:1) ZDDP 68649-42-3 

Diacel LWL Cellulose derivative None 

Diesel Fuel Diesel 68476-34-6 

Doc-3 Surfactant Imidazoline 

Isopropanol

None 

 67-63-0 

Dual Spacer 

Aluminum Oxide 

Crystalline Silica, Quartz 

Diatomaceous Earth 

Silica, amorphous-diatomaceous Earth 

1344-28-1 

14808-60-7 

61790-53-2 

68855-54-9 

Econolite Additive Sodium Metasilicate, Anhydrous 6834-92-0 

Econoprop Proppant Aluminum Silicate 

Crystalline Silica, Cristobalite 

1302-76-7 

14464-46-1 

Electro Wash 2000 

Ethanol

Ethyl Acetate 

Isopropanol

Naphtha

 64-17-5 

141-78-6 

 67-63-0 

 64741-66-8 

U112 5,000 

Enamel, Cote All (Yellow, Red, 

Neutral) 

Crystalline Silica 

Ethyl Benzene 

Mineral Spirits 

14808-60-7 

100-41-4 

64742-48-9 

None 1,000 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-3 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Enamel, Engine Black #203 

Butane

Carbon Black 

Dimethyl Ketone 

Ethyl 3-Ethoxypropionate 

Ethyl Acetate 

Ethylbenzene

Methyl Ethyl Ketone 

Propane

Proprietary Resin 

Xylene (W/ Anti-Static) 

 106-97-8 

1333-86-4 

67-64-1 

763-69-9 

141-78-6 

 100-41-4 

78-93-3 

 74-98-6 

None 

1330-20-7 

U002 

U112 

None 

U159 

U239 

5,000 

5,000 

1,000 

5,000 

100 

Enamel, Gloss Gray 610 

Series 2 

Alkyd Resin 

Alkyd Resin Titanium Dioxide (total 

dust) 

Aluminum Oxides 

Amorphous Silica 

Mineral Spirits as Stoddard Solvent 

None 

13463-67-7 

1344-28-1 

7631-86-9 

8052-41-3 

Enamel, Gloss Protective Blue 

#7722830 

1,2,4-Trimethylbenzene

Acetone

Aliphatic Hydrocarbon 

Aromatic Hydrocarbon 

Aromatic Solvent 

Ethylbenzene

Ethylene Glycol Monobutyl Ether 

Liquefied Petroleum Gas 

Magnesium Silicate 

N-Butyl Acetate 

Pigment Black 7 

Pigment Red 122 

Pigment Violet 32 

Propylene Carbonate 

Stoddard Solvent 

Titanium Dioxide 

Toluene

Xylene

 95-63-6 

 67-64-1 

64742-89-8 

64742-95-6 

64742-95-6 

 100-41-4 

111-76-2 

68476-86-8 

14807-96-6 

123-86-4 

1333-86-4 

980-26-7 

12225-08-0 

108-32-7 

8052-41-3 

13463-67-7 

 108-88-3 

 1330-20-7 

U002 

None 

None 

U109 

U239 

5,000 

1,000 

5,000 

10 

100 

Enamel, Industrial Tough Coat, 

OSHA Blue # 1510 

1-Methoxy-2-Propanol Acetate 

Acetone

Butane

Ethylbenzene

Methyl Ethyl Ketone 

Methyl Isobutyl Ketone 

Propane

Titanium Dioxide 

Xylene

108-65-6 

 67-64-1 

 106-97-8 

 100-41-4 

78-93-3 

108-10-1 

 74-98-6 

13463-67-7 

 1330-20-7 

U002 

None 

U159 

U161 

U239 

5,000 

1,000 

5,000 

5,000 

100 

Enamel, Industrial Tough Coat, 

OSHA Red #2116 

1-Methoxy-2-Propanol Acetate 

Acetone

Butane

Ethylbenzene

Methyl Ethyl Ketone 

Methyl Isobutyl Ketone 

Propane

Xylene

108-65-6 

 67-64-1 

 106-97-8 

 100-41-4 

78-93-3 

108-10-1 

 74-98-6 

 1330-20-7 

U002 

None 

U159 

U161 

U239 

5,000 

1,000 

5,000 

5,000 

100 

K-4 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Enamel, Industrial Yellow, 

944300, 9444402, 944504 

Calcium Aluminum Silicate 

Magnesium Silicate 

Pigment Black 7 

Pigment Orange 5 

Pigment Red 3 

Pigment Yellow 74 

Stoddard Solvent 

Titanium Dioxide 

1332-58-7 

14807-96-6 

1333-86-4 

3468-63-1 

2425-85-6 

6358-31-2 

8052-41-3 

13463-67-7 

Enamel, Interior-Exterior (Tile 

Gray #71) 

(As Nuisance Particulates) 

(As Nuisance Particulates) 

Carbon Black 

Sodium Potassium Aluminum Silicate 

Titanium Dioxide 

1317-80-2 

37244-96-5 

1333-86-4 

37244-96-5 

1317-80-2 

Enamel, Metallic (Silver) 400 

Acetone

Aliphatic Hydrocarbon Solvent 

Ethylbenzene

Mineral Spirits 

Propane

Toluene

V. M. & P. Naphtha 

Xylene

 67-64-1 

64742-89-8 

 100-41-4 

64742-88-7 

 74-98-6 

 108-88-3 

64742-89-8 

 1330-20-7 

U002 

None 

U109 

U239 

5,000 

1,000 

10 

100 

Enamel, Premium Gloss 

Protective Blue #7727830 

1,2,4-Trimethylbenzene

Acetone

Aliphatic Hydrocarbon 

Aromatic Hydrocarbon 

Aromatic Solvent 

Ethylbenzene

Ethylene Glycol Monobutyl Ether 

Liquefied Petroleum Gas 

Magnesium Silicate 

N-Butyl Acetate 

Pigment Black 7 

Pigment Red 122 

Pigment Violet 32 

Propylene Carbonate 

Stoddard Solvent 

Titanium Dioxide 

Toluene

Xylene

 95-63-6 

 67-64-1 

64742-89-8 

64742-95-6 

64742-95-6 

 100-41-4 

111-76-2 

68476-86-8 

14807-96-6 

123-86-4 

1333-86-4 

980-26-7 

12225-08-0 

108-32-7 

8052-41-3 

13463-67-7 

 108-88-3 

 1330-20-7 

U002 

None 

None 

U109 

U239 

5,000 

1,000 

5,000 

10 

100 

Enamel, Premium Gloss 

Protective Blue # 7724830 

1,2,4-Trimethylbenzene

Acetone

Aliphatic Hydrocarbon 

Aromatic Hydrocarbon 

Aromatic Solvent 

Ethylbenzene

Ethylene Glycol Monobutyl Ether 

Liquefied Petroleum Gas 

Magnesium Silicate 

N-Butyl Acetate 

Pigment Black 7 

Pigment Red 122 

 95-63-6 

 67-64-1 

64742-89-8 

64742-95-6 

64742-95-6 

 100-41-4 

111-76-2 

68476-86-8 

14807-96-6 

123-86-4 

1333-86-4 

980-26-7 

U002 

None 

None 

5,000 

1,000 

5,000 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-5 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Enamel, Premium Gloss 

Protective Blue # 7724830, 

continued 

Pigment Violet 32 

Propylene Carbonate 

Stoddard Solvent 

Titanium Dioxide 

Toluene

Xylene

12225-08-0 

108-32-7 

8052-41-3 

13463-67-7 

 108-88-3 

 1330-20-7 

U109 

U239 

10 

100 

Enamel, Premium Gloss 

Protective Green #7738830 

1,2,4-Trimethylbenzene

Acetone

Aliphatic Hydrocarbon 

Aromatic Hydrocarbon 

Aromatic Solvent 

Ethylbenzene

Ethylene Glycol Monobutyl Ether 

Liquefied Petroleum Gas 

Magnesium Silicate 

N-Butyl Acetate 

Pigment Black 7 

Pigment Red 122 

Pigment Violet 32 

Propylene Carbonate 

Stoddard Solvent 

Titanium Dioxide 

Toluene

Xylene

 95-63-6 

 67-64-1 

64742-89-8 

64742-95-6 

64742-95-6 

 100-41-4 

111-76-2 

68476-86-8 

14807-96-6 

123-86-4 

1333-86-4 

980-26-7 

12225-08-0 

108-32-7 

8052-41-3 

13463-67-7 

 108-88-3 

 1330-20-7 

U002 

None 

None 

U109 

U239 

5,000 

1,000 

5,000 

10 

100 

Enamel, Premium Gloss 

Protective Red #7763830 

1,2,4-Trimethylbenzene

Acetone

Aliphatic Hydrocarbon 

Aromatic Hydrocarbon 

Aromatic Solvent 

Ethylbenzene

Ethylene Glycol Monobutyl Ether 

Liquefied Petroleum Gas 

Magnesium Silicate 

N-Butyl Acetate 

Pigment Black 7 

Pigment Red 122 

Pigment Violet 32 

Propylene Carbonate 

Stoddard Solvent 

Titanium Dioxide 

Toluene

Xylene

 95-63-6 

 67-64-1 

64742-89-8 

64742-95-6 

64742-95-6 

 100-41-4 

111-76-2 

68476-86-8 

14807-96-6 

123-86-4 

1333-86-4 

980-26-7 

12225-08-0 

108-32-7 

8052-41-3 

13463-67-7 

 108-88-3 

 1330-20-7 

U002 

None 

None 

U109 

U239 

5,000 

1,000 

5,000 

10 

100 

Enamel, Premium Orange 

#789882 MSDS Not Found None 

Enamel, Super Tough Coat 

(Black 729-0604) 

2-(2-Methoxyethoxy) -ethanol 

Carbon Black 

111-77-3 

1333-86-4 

Enamel, Tan 

Crystalline Silica 

Ethyl Benzene 

Mineral Spirits 

14808-60-7 

100-41-4 

64742-48-9 

None 1,000 

ES Coolant Blends MSDS Not Found None 

K-6 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Ethylene Glycol Monobutyl 

Ether Ethylene Glycol Monobutyl Ether 111-76-2 

FDP-S704-03 MSDS Not Found None 

FDP-S714-04 MSDS Not Found None 

FDP-S816-05 MSDS Not Found None 

FE-1A Acidizing Composition Acetic Acid 

Acetic Anhydride 

64-19-7 

108-24-7 

None 

None 

5,000 

5,000 

Ferchek A Reducing Agent 

Citric Acid 

Hydroxylamine Hydrochloride 

Silica, Amporphous-Fumed 

77-92-9 

5470-11-1 

7631-86-9 

Ferrotrol 300L (Iron Control) MSDS Not Found 

Finish, Gloss White V2192833 

Acetone

Aliphatic Petroleum Distillate 

Ethylbenzene

Liquefied Petroleum Gas 

Magnesium Silicate 

Titanium Dioxide 

Toluene

Xylene

 67-64-1 

64742-48-9 

 100-41-4 

68476-86-8 

14807-96-6 

13463-67-7 

 108-88-3 

 1330-20-7 

U002 

None 

U109 

U239 

5,000 

1,000 

10 

100 

Finish, Safety Red V2164838 

Acetone

Ethylbenzene

Ethylene Glycol Monobutyl Ether 

Liquefied Petroleum Gas 

N-Butyl Acetate 

Xylene

 67-64-1 

 100-41-4 

111-76-2 

68476-86-8 

123-86-4 

 1330-20-7 

U002 

None 

None 

U239 

5,000 

1000 

5,000 

100 

Flocelle 3/8" MSDS Not Found None 

FMS375 Foamer Stick MSDS Not Found None 

FMW3032 Foamer MSDS Not Found None 

Foam Soap, Aero green 

2-bromo-2-nitropropane-1, 3-diol 

Citric Acid 

Cocamidopropyl Betaine 

D&C Green No.5 

FD&C Yellow No.5 

Fragrance

PPG-24-Glycereth-24

Propylene Glycol 

Sadium Laureth Sulfate 

Tetrasodium EDTA 

Triclosan 

Water 

52-51-7 

77-92-9 

61789-40-4 

4403-90-1 

1934-21-0 

 None 

 9082-00-2 

57-55-6 

68585-34-2 

64-02-8 

3380-34-5 

7732-18-5 

FR-26LC 

Hydrotreated Light Petroleum Distillate 

Hydrotreated Light Petroleum Distillate 

9-Octadecenamide, n, n-bis-2(hydroxyethyl)-,(Z) 

Acrylamide Copolymer 

Hydrotreated Light Petroleum Distillate 

64742-47-8 

64742-47-8 

93-83-4 

None 

64742-47-8 

FR-56 Hydrotreated Light Petroleum Distillate 64742-47-8 

Future Floor Finish 

Diethylene Glycol Methyl Ether 

Modified Acrylic Copolymer 

Tributoxy Ethyl Phosphate 

Water 

111-90-0 

None 

000078-51-3 

7732-18-5 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-7 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Gasoila WFP (Water Finding 

Paste) Triethanolamine 102-71-6 

Gasoline Gauging Paste All Ingredients Non Hazardous None 

GBW-30 Breaker Carbohydrates

Hemicellulase Enzyme 

 None 

9012-54-8 

Gel-Sta L Stabilizer Sodium Thiosulfate 7772-98-7 

Gel-Sta Stabilizer Sodium Thiosulfate 7772-98-7 

Gilsonite Resin Natural Asphalt 12002-43-6 

Glade Spin Fresh (Toilet Paper 

Rollers) 

Sodium Silico Aluminate 

Sodium Siulfate 

None 

None 

Gone, Carpet Spot Cleaner 

Dipropylene Glycol Butyl Ether 

Linear Alkyl Benzene Sulfonic Acid 

Perfume, Coloring and Additives less 

than 1% 

Soft Water 

29911-28-2 

68584-22-5 

None 

7732-18-5 

GP Forward General Purpose 

Cleaner 

Alochol Ethoxylates 

Propylene Glycol Methyl Ether 

68439-46-3 

107-98-2 

Grease, #105 Motor Assembly 

Calcium Thickener 

Mineral Oil 

Zinc Oxide 

68309-87-5 

64742-52-5 

1314-13-2 

Grease, Chevron Ultra Duty 

EP 

Highly Refined Mineral Oil 

Zinc Dialkyldithiophosphate 

Mixture 

68649-42-3 

Grease, Super Lube #2 

Additives

Lubricant Base Oil (Petroleum) 

Zinc Compounds 

 PROPRIETARY 

Various 

PROPRIETARY 

HAI-60 Acid Inhibitor Potassium Iodide 7681-11-0 

HAI-85M Acid Inhibitor 

Copper Iodide 

Dimethyl Formamide 

Ehtyl Octynol 

Isopropanol

Propargyl Alcohol 

Quaternary Ammonium Salts 

7681-65-4 

68-12-2 

5877-42-9 

 67-63-0 

107-19-7 

None 

P102 1,000 

Halad 322 Cement Additive 

Cellulose derivative 

Sodium hydroxide 

Sulfonic Acid Salt 

Modified Acrylic Copolymer 

Sodium Hydroxide 

Acrylic Resin 

Sodium hydroxide 

MSDS Not Found 

None 

1310-73-2 

None 

None 

1310-73-2 

Mixture 

1310-73-2 

None 

None 

None 

1,000 

1,000 

1,000 

Halad 9 Cement Additive MSDS Not Found None 

Halliburton Super Flush 

Additive 

Crystalline Silica, Quartz 

Silica, amorphous-diatomaceous Earth 

Sodium Bicarbonate 

Sodium Metasilicate, Anhydrous 

14808-60-7 

68855-54-9 

144-55-8 

6834-92-0 

Halliburton Weld A Converter 

Penetaethylenehexamine

Tetraethylenepentamine

Triethanolamine 

 4067-16-7 

 112-57-2 

112-24-3 

K-8 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Halliburton Weld A Resin 

Aluminum

Butyl Glycidyl Ether 

Calcium Carbonate 

Crystalline Silica, Quartz 

Epoxy Resin 

 7429-90-5 

None 

471-34-1 

14808-60-7 

None 

Hand Cleaner, Fast Orange 

23108 

D-Limonene

Ethoxylated C11-C16 Alcohol 

Pumice

Silica Quartz 

Water 

 5989-27-5 

127036-24-2 

 1332-09-8 

14808-60-7 

7732-18-5 

HC-2 Inner Salt of Alhyl Amines 

Sodium Chloride 

None 

7647-14-5 

Hi-Dense No. 4 Weight 

Additive 

Aluminum Oxide 

Crystalline Silica, Quartz 

Iron Oxide 

1344-28-1 

14808-60-7 

1309-37-1 

High Performance Lubricant 

Syn Film 32 MSDS Not Found None 

HI-M-PACT 5458 Kinetic 

Hydrate Inhibitor 

MSDS Not Found 

MSDS Not Found 

None 

Howco Gel (Bentonite) 

Bentonite

Crystalline Silica, Cristobalite 

Crystalline Silica, Quartz 

Crystalline Silica, Tridymite 

 1302-78-9 

14464-46-1 

14808-60-7 

15468-32-3 

Howco Suds Sticks Polyethylene Glycol 25322-68-3 

 Sodium Chloride 7647-14-5 

Howco-Suds Foaming Agent MSDS Not Found 

HPT-1 No-Hazardous Substances None 

HR-12 Additive Modified Lignosulfonate None 

HR-5 Additive Modified Lignosulfonate None 

HT Breaker Tert-Butyl Hydroperoxide 75-91-2 

Hydraulic Jack Oil #80054 

Distillates (petroleum), Hydrotreated 

Naphthenic 

Polymethacrylate Dispersion 

64742-53-6 

Mixture 

Hydrochloric Acid (HCl) MSDS Not Found None 

Hydroclear Super SAE 30 Oil 

Additives

Lubricant Base Oil (Petroleum) 

p-dodecylphenol

 PROPRIETARY 

Various 

 74499-35-7 

Hydrochloric Acid Hydrocloric Acid 7647-01-0 None 5,000 

HYG-3 Fumaric Acid 110-17-8 None 5,000 

HyTemp I (Inhibitor-Intensifier) MSDS Not Found None 

Injectrol Component A Sodium Silicate 1344-09-8 

Injectrol G Sodium Acid Pyrophosphate 

Sodium Silicate 

7758-16-9 

1344-09-8 

Isobutylene Isobutene 115-11-7 

Isopropyl Alcohol Isopropanol 67-63-0 

Jump Start Starting Fluid 

#05761 

Carbon Dioxide 

Diethyl Ether 

Heptane

Upper Cylinder Lubricant 

124-38-9 

60-29-7 

 142-82-5 

64741-89-5 

U117 100 

K-34 Sodium Bicarbonate 144-55-8 

K-35 Sodium Carbonate 497-19-8 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-9 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

KCL Potassium Chloride Potassium Chloride 7447-40-7 

KEM Hi-Temp (Heat Resistant 

Ctg.) 1500 #10, #14 

1,2,4-Trimethylbenzene

1,3,5-Trimethylbenzene

Cumene 

Ethylbenzene

Light Aromatic Hydrocarbons 

Mineral Spirits 

Xylene

 95-63-6 

 108-67-8 

98-82-8

 100-41-4 

64742-95-6 

64742-88-7 

 1330-20-7 

 U109

None 

U239 

10 

1000 

100 

Kopr Kote (Anti-Seize 

Lubricant) 

Metallic Copper 

Nonhazardous Blend 

Petroleum Oil 

744-050-8 

829-805-49 

64742-65-0 

Kwik Seal Additive No-Hazardous Substances Mixture 

Kwik-Seal (Blend nut hulls, 

wood fiber, cellophane) MSDS Not Found None 

Leak detector, SNOOP Surfactant

Water 

 Not Available 

7732-18-5 

Lemon Oil Polish Aliphatic Petroleum Distillate 

Paraffinic Petroleum Distillate 

64742-06-9 

64742-65-0 

LGC-35 CBM Paraffinic Solvent 

Polysaccharide 

None 

None 

LGC-8M Guar Gum 9000-30-0 

LGC-V Diesel

Guar Gum Derivative 

 68476-34-6 

None 

LGC-VI Diesel

Guar Gum Derivative 

 68476-34-6 

None 

Lime (Calcium Hydroxide) MSDS Not Found None 

Liquid Wrench Lubricant #L312 

Carbon Dioxide 

Naphthenic Petroleum Distillate 

Tetrachloroethylene 

124-38-9 

64742-52-5 

127-18-4 U210 100 

Long Life Multi-Purpose 

Lubricant #1603 MSDS Not Found None 

Losurf-259 Surfactant Heavy Aromatic Petroleum Naphtha 

Isopropanol

64742-94-5 

 67-63-0 

Losurf-300 Nonionic Surfactant Ethoxylated Nonylphenol None 

Lubricant, Power 4-HD-PSP200 Synthetic Blend MSDS Not Found None 

Lubricant, Power 5-TC-30 

Synthetic Blend MSDS Not Found None 

Lysol Plus Bleach 

Alkyl (C12-C16) Dimethyl Benzyl 

Ammonium Chlorides 

Alkyl (C12-C18) Dimethyl Benzyl 

Ammonium Chloride 

68424-66-1 

68391-01-5 

Marvel Mystery Oil 

Chlorinated Hydrocrabons 

Mineral Spirits 

Napthenic Hydrocarbons 

00095-50-1 

08052-41-3 

64742-52-5 

U109 10 

Matrixflo II Dimethyl Glutarate 1119-40-0 

MC PDX-4500 Foaming Agent MSDS Not Found None 

Methanol Methanol

MSDS Not Found 

 67-56-1 U154 5,000 

MF-1 Sodium Acid Pyrophosphate 7758-16-9 

K-10 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

MI Gel (Sodium 

Montmorillonite) MSDS Not Found None 

Microbond Expanding Additive Calcium Hydroxide 1305-62-0 

Microbond HT Cement Magnesium Oxide 1309-48-4 

MO-67 Sodium hydroxide 1310-73-2 None 1000 

Modified Gauging PasteMethonol Methanol 67-56-1 U154 5,000 

Modified Water Finding Paste 

M-3 All Ingredients Non Hazardous None 

Morflo III Surfactant 1-Methoxy-2-Propanol 

Dodecylbenzene Sulfonic Acid 

107-98-2 

27176-87-0 None 1,000 

Murphy’s Oil Soap None None 

Musol A Solvent Oxylated Alcohol None 

Natural Gas 

Ethane

Methane

Propane 

MSDS Not Found 

 74-84-0 

 74-82-8 

74-98-6 

NE-118 (Non-Emulsifying 

Agent) MSDS Not Found None 

Nitrogen Liquefied Nitrogen 7727-37-9 

Nitrogen, Gas Nitrogen 7727-37-9 

No 327 Armor Plate w/Moly-D MSDS Not Found 

No. 1 Thinner Mineral Spirits as Stoddard Solvent 8052-41-3 

Non-Flammable 19% O2, 25% 

LEL Pentane, H2S, N2 

Carbon Monoxide 

Hydrogen Sulfide 

Methane

Nitrogen

Oxygen

630-08-0 

7783-06-4 

 74-82-8 

 7727-37-9 

 7782-44-7 

U135 100 

Optiflo-HTE Crystalline Silica, Quartz 

Walnut Hulls 

14808-60-7 

Mixture 

Optiflo-II Delayed Release 

Breaker 

Ammonium Persulfate 

Crystalline Silica, Quartz 

7727-54-0 

14808-60-7 

Optiflo-III Delayed Release 

Breaker 

Ammonium Persulfate 

Crystalline Silica, Quartz 

7727-54-0 

14808-60-7 

Optiflo-LT Delayed Release 

Breaker 

Citric Acid 

Polyvinylidene Chloride 

77-92-9 

9002-85-1 

Orange Hand Cleaner, LC 

25108 

Castor Oil 

D-Limonene

Ethoxylated C11-C16 Alcohol 

Propylene Glycol 

Pumice

Silica Quartz 

Water 

8001-79-4 

 5989-27-5 

127036-24-2 

57-55-6 

 1332-09-8 

14808-60-7 

7732-18-5 

Pacemaker T-68 

Distillates, Petroleum, Hydrotreated 

heavy paraffinic 

Distillates, Petroleum, Solvent-refined 

heavy paraffinic 

Proprietary Ingredients 

64742-54-7 

64741-88-4 

Mixture 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-11 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Paint & Varnish Remover, 

Kwik All Purpose 

Ethylene Glycol Monobutyl 

Isopropanol

Methanol

Methylene Chloride 

Water 

111-76-2 

 67-63-0 

 67-56-1 

75-09-2 

7732-18-5 

U154 

U080 

5,000 

1,000 

Paint Marking Orange 

V2344834, V2345828 

Aromatic Hydrocarbon 

Hydrotreated Light Distillate 

Liquefied Petroleum Gas 

Magnesium Silicate 

Naphtha

Polymer Anchored Green Dye 

Dispersion 

Toluene

Xylene

64742-95-6 

64742-47-8 

68476-86-8 

14807-96-6 

 8032-32-4 

Mixture 

 108-88-3 

 1330-20-7 

U109 

U239 

10 

100 

Paint, Interior-Exterior 1504 

1-Butanol

1-Methoxy-2-Propanol Acetate 

Acetone

Butane

Ethylbenzene

Methyl Ethyl Ketone 

Methyl Isobutyl Ketone 

Propane

Titanium Dioxide 

Xylene

 71-36-3 

108-65-6 

 67-64-1 

 106-97-8 

 100-41-4 

78-93-3 

108-10-1 

 74-98-6 

13463-67-7 

 1330-20-7 

U031 

U002 

None 

U159 

U161 

U239 

5,000 

5,000 

1,000 

5,000 

5,000 

100 

Paint, Interior-Exterior Black 

1601 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Interior-Exterior Blue 

3546 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Interior-Exterior Clear 

1301 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Interior-Exterior Green 

2001 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Interior-Exterior White 

1501 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Interior-Exterior Yellow 

1806 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Inverted Orange 

Marking Paint RDMI 1000 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Semi-Gloss House & 

Trim White 9500 

Ethylene Glycol 

Proprietary Additive 

Proprietary Pigment 

107-21-1 

None 

None 

None 5,000 

Paint, Spray Green 2324 See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Spray OSHA Orange 

2410 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Paint, Spray OSHA Yellow 

1813 

See Sherwin Williams (krylon) Paint, 

Interior-Exterior 1504 None 

Para-Dichlorobenzene Urinal 

blockers p-Dichlorobenzene (a,b,c,d,e,f) 106-46-7 U109 10 

Parts Cleaning Fluid, Agitene Aliphatic Petroleum Distillate 

DPM (Dipropylene Glycol Methyl Ether) 

64742-88-7 

34590-94-8 

PEN-88 Oxylated Alcohol None 

K-12 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Pine Sol 

Alkyl alcohol ethoxylates 

Isopropyl alcohol 

Pine oil 

Sodium petroleum sulfonate 

127036-24-2 

67-63-0 

8002-09-3 

68608-26-4 

Pledge, Lemon Scent 

Butane

Isobutane

Isoparaffinic Hydrocarbon Solvent 

Propane

Silicones

Water 

 106-97-8 

 75-28-5 

64741-66-8 

 74-98-6 

 63148-62-9 

7732-18-5 

Porter Guard Fast Dry Enamel 

(As Nuisance Particulates) 

(As Silica, Crystalline and Quartz) 

(As Talc containing non-asbestos 

fibers) 

(As Talc containing non-asbestos 

fibers) 

(As Zinc Compounds) 

Antigorite

Aromatic Naphtha 

Mica

Naphtha

Quartz 

Sodium Potassium Aluminum Silicate 

Talc 

Termolite 

Xylenes

Zinc Oxide 

37244-96-5 

14808-60-7 

12135-86-3 

14567-73-8 

1314-13-2 

 12135-86-3 

64742-95-6 

 12001-26-2 

 8052-41-3 

14808-60-7 

37244-96-5 

14807-96-6 

None 

 1330-20-7 

1314-13-2 

U239 100 

Pozmix A Crystalline Silica, Cristobalite 

Fly Ash 

14464-46-1 

68131-74-8 

Primer #30753 

Acetone

Cyclohexanone

Methyl Ethyl Ketone 

Tetrahydrofuran 

 67-64-1 

 108-94-1 

78-93-3 

109-99-9

U002 

U057 

U159 

 U124

5,000 

5,000 

5,000 

100 

Primer, Red V2169838 

Acetone

Basic Zinc Molybdate 

Ethylbenzene

Liquefied Petroleum Gas 

Magnesium Silicate 

N-Butyl Acetate 

Stoddard Solvent 

Titanium Dioxide 

Xylene

Zinc Phosphate 

 67-64-1 

61583-60-6 

 100-41-4 

68476-86-8 

14807-96-6 

123-86-4 

8052-41-3 

13463-67-7 

 1330-20-7 

7779-90-0 

U002 

None 

None 

U239 

5,000 

1,000 

5,000 

100 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-13 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Primer, Sandable Gray 1318 

2-Methyl-1-Propanol

Acetone

Butane

Calcium Carbonate 

Propane

Talc 

Titanium Dioxide 

Toluene 

V. M. & P. Naphtha 

 78-83-1 

 67-64-1 

 106-97-8 

471-34-1 

 74-98-6 

14807-96-6 

13463-67-7 

108-8-3

64742-89-8 

U140 

U002 

 U109

5,000 

5,000 

10 

Primer/Sealer White 8520 

Primer/Sealer, Interior Latex 

(White 728-9416) 

Ethylbenzene

Mineral Spirits 

Mineral Spirits 140-Flash 

Talc 

Titanium Dioxide 

Xylene

Cristobalite

Ethylene Glycol 

Kaolin 

Quartz 

Titanium Dioxide 

 100-41-4 

64742-88-7 

64742-88-7 

14807-96-6 

13463-67-7 

 1330-20-7 

 14464-46-1 

107-21-1 

1332-58-7 

14808-60-7 

13463-67-7 

None 

U239 

None 

1,000 

100 

5,000 

Produced Water Produced water None 

Propane Propane 74-98-6 

PVC Cement 1200 

Acrylic Resin 

Amorphous fumed Silica (nonhazardous) 

Cyclohexanone

Methyl Ethyl Ketone 

PVC Resin (Non-Hazardous) 

Tetrahydrofuran 

96-33-3 

112945-52-5 

 108-94-1 

78-93-3 

9002-86-2 

109-99-9

U057 

U159 

 U124

5,000 

5,000 

100 

PVC Solvent Cement 

Acetone

Cyclohexanone

Methyl Ethyl Ketone 

PVC Resin (Non-Hazardous) 

Tetrahydrofuran 

 67-64-1 

 108-94-1 

78-93-3 

9002-86-2 

109-99-9

U002 

U057 

U159 

 U124

5,000 

5,000 

5,000 

100 

QD Contact Cleaner #02130 

1,1-Difluoroethane (HFC-152a) 

Hexane Isomers 

Methanol

n-Hexane

Synthetic Isoparaffinic Hydrocarbon 

75-37-6 

Various 

 67-56-1 

 110-54-3 

64741-66-8 

U154 5,000 

Raid 

2-Phenethyl Propionate 

Eugenol

Isoparaffinic Hydrocarbon Solvent 

Propellant 

Solvents 

None 

 None 

None 

None 

None 

Resolve Isopropyl alcohol 

Propylene Glycol Monomethyl Ether 

67-63-0 

107-98-2 

Reverse Demulsifier 

RBW0118D MSDS Not Found None 

Ro-Rep MSDS Not Found None 

K-14 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Round-Up Weed Killer 

Biocide 

Glyphosate Isopropylamine salt 

Stabilizer 

Surfactant 

Water 

38641-94-0 

7732-18-5 

Rush Safety Solvent MSDS Not Found None 

S-400 (Surfactant) MSDS Not Found None 

SAE 5AW-30 Motor Oil Additives

Lubricant Base Oil (Petroleum) 

 PROPRIETARY 

Various 

Salt, Oilfield Fine Sodium Chloride 7647-14-5 

Salt, Ottawa MSDS Not Found None 

Sand- 40/60 Wedron Special 

Frac Crystalline Silica, Quartz 14808-60-7 

Sand- Oklahoma No. 1- SSA-2 Crystalline Silica, Quartz 14808-60-7 

SandWedge NT Heavy Aromatic Petroleum Naphtha 64742-94-5 

SCA-130 Inhibitor 

Acetaidehyde 

Aldol

Crotonaidehyde 

75-07-0 

 107-89-1 

123-73-9 U053 100 

Scotchrap Brand Pipe Primer 

Benzene 

Butyl rubber 

Calcium Zinc Resinate 

Carbon Black 

Ethyl Alcohol 

Kaolinite

Mica-Group Minerals 

Peperylene-2-Methyl-2-Butene Polymer 

Quartz Silica 

Solvent Naphtha (Petroleum), Light 

Aliphatic 

Toluene

71-43-2 

9010-85-9 

68334-35-0 

1333-86-4 

64-17-5 

 1318-74-7 

12001-26-2 

26813-14-9 

14808-60-7 

64742-89-8 

 108-88-3 

U109 

U109 

10 

10 

Scrubs, Rough Touch 

Cocoamide DEA 

Ethoxylated Alcohols (C12-15 Pareth-7) 

Isoparaffinic Hydrocarbon 

Mineral Oil (mist) 

Oleic Acid 

Propylene Glycol 

Pumice (dust) 

Triethanolamine 

Water 

68603-42-9 

68131-39-5 

64742-47-8 

8042-47-5 

61790-12-3 

57-55-6 

1332-09-8 

102-71-6 

7732-18-5 

Sealant, #5 Pipe Thread 

#25431 Diacetone Alcohol 123-42-2 

Sealant, #5 Pipe Thread 

Special #26431 Diethylene Glycol Methyl Ether 111-90-0 

Sealant, 736 RTV Ethyltriacetoxysilane

Methyltriacetoxysilane

 17689-77-9 

 4253-34-3 

SGA-1 Gelling Agent Acetic Acid 64-19-7 None 5,000 

SGA-HT Gelling Agent 

Branched Ethoxylated Nonylphenol 

Hydrotreated Heavy Naphthenic 

Distillate 

68412-54-4 

64742-52-5 

SI-16 WSP MSDS Not Found None 

Silica Flour-SSA-1 Crystalline Silica, Quartz 14808-60-7 

Silicalite- Compacted Silica, Amporphous-Fumed 7631-86-9 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-15 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Silicone Ad Sealant, Red High 

Temp RTV 

Acetic Acid 

Dimethyl polysiloxane 

Distillates (petroleum), hydrotreated 

middle 

Ethyltriacetoxysilane

Methyltriacetoxysilane

Poly(dimethylsiloxane), hydroxy 

terminated 

Silica, amorphous (fumed) 

64-19-7 

63148-62-9 

64742-46-7 

 17689-77-9 

 4253-34-3 

70131-67-8 

7631-86-9 

None 5,000 

Silicone Sealant, RD Pro RTV 

Dimethylsiloxane, hydroxy-terminated 

Ethyltriacetoxysilane

Iron (III) Oxide 

Methyltriacetoxysilane

Non-hazardous ingredients 

Polydimethylsiloxane 

Silica (as amorphous silica, total dust) 

Titanium Dioxide 

70131-67-8 

 17689-77-9 

1309-37-1 

 4253-34-3 

None 

63148-62-9 

7631-86-9 

13463-67-7 

Silicone, High T RTV #81409 

Acetic Acid 

Amorphous Silica 

Distillates (petroleum), Hydrotreated 

Middle 

Ethyltriacetoxysilane

Iron Oxide 

Methyltriacetoxysilane

Poly (Dimethylsiloxane), Hydroxy 

Terminated 

Polydimethylsiloxane 

Titanium Dioxide 

64-19-7 

7631-86-9 

64742-46-7 

 17689-77-9 

1309-37-1 

 4253-34-3 

70131-67-8 

63148-62-9 

13463-67-7 

None 5,000 

Skid Tex for Paint Pumice 

Quartz 

1332-09-8 

14808-60-7 

Slick Willie- OF WSP MSDS Not Found None 

Snapback Spraybuff Liquid Diethylene Glycol monoethyl Ether 111-90-0 

Snow & Ice Melt 

Calcium Chloride 

Potassium Chloride 

Sodium Chloride 

010043-52-4 

07447-40-7 

7647-14-5 

Soda Ash (Sodium Carbonate) MSDS Not Found None 

Sodium Bicarbonate MSDS Not Found None 

Sodium Persulfate Sodium Persulfate 7775-27-1 

Solidifier, Belzona 1221Supere Metal MSDS Not Found None 

Solidifier, Belzona 1321 

Ceramic S-Metal (Blue/Gray) MSDS Not Found None 

Soltex (Sodium Asphalt 

Sulfonate) MSDS Not Found None 

SP Breaker Sodium Persulfate 7775-27-1 

SP-101 (Sodium Polyacrylate) MSDS Not Found None 

Spartan Pine Cleaner 

Pine Oil 

Potassium Cocoate 

Sodium Xylene Sulfonate 

8002-09-3 

61789-30-8 

1300-72-7 

SSO-21 Diethylene Glycol 111-46-6 

K-16 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

SSO-21M Winterized 

Ethoxylated Nonylphenol 

Ethylene Glycol Monobutyl Ether 

Methanol

None 

111-76-2 

 67-56-1 U154 5,000 

Stannic Chloride Tin Chloride 7646-78-8 

Starting Fluid, SFR-11 

Carbon Dioxide 

Ethyl Ether 

n-Heptane

124-38-9 

60-29-7 

 142-82-5 

U117 100 

Stihl 2 Cycle Universal Engine 

Oil #07813198903 

Additive Package 

Dye 

Petroleum Distillates, Hydrotreated 

Heavy Paraffnic 

Petroleum Distillates, Solvent Dewaxed 

Heavy Paraffinic 

Residual Oils (petroleum), Hydrotreated 

Residual Oils (petroleum), Solvent 

Dewaxed 

Stoddard Solvent 

Mixture 

Mixture 

64742-54-7 

64742-65-0 

64742-57-0 

64742-62-7 

8052-41-3 

Strawberry Fragrance Master MSDS Not Found None 

Stride Floral MSDS Not Found None 

Sugar Cane Sucrose Carbohydrates None 

Super CBL Additive Aluminum 7429-90-5 

Super HS Bauxite (20-40 

Mesh) 

Aluminum Oxide 

Aluminum Silicate 

Phenol/Formaldehyde resin 

1344-28-1 

1302-76-7 

9003-35-4 

Super Prop Propant Phenol/Formaldehyde resin 9003-35-4 

Terminator 

Alkyloxypolyethyleneoxyethanol

Blend of n-Alkyl Dimethyl Benzyl and 

Di-n-alky Dimethyl Ammonium 

Chlorides 

Perfume, Coloring and Additives less 

than 1% 

Soft Water 

Tetrasodium Ethylenediammine 

Teraacetate 

 84133-50-6 

68424-85-1 

68424-94-3 

None 

7732-18-5 

64-02-8 

TFE Seal/ Valve Lubricant MSDS Not Found None 

Thinner #641 MSDS Not Found None 

Time Mist Air Freshener 

Acetone

C8-C9 Isoparaffnic Hydrocarbons 

Diethylene Glycol Methyl Ether 

Perfume Oils-Supplier Trade Secret 

Propane

 67-64-1 

64742-48-9 

111-90-0 

None 

 74-98-6 

U002 5,000 

TLC-80 Aluminum Oxide 1344-28-1 

TLC-W3-Rock Salt Crystalline Silica, Cristobalite 14464-46-1 

Toluene Toluene 108-88-3 U109 10 

Triethylene Glycol MSDS Not Found None 

Universal Solvent Blend 

Acetone

Ester EEP 

n-Butane

Propane

 67-64-1 

763-69-9 

 106-97-8 

 74-98-6 

U002 5,000 

Unleaded Gasoline 

Benzene 

Gasoline

71-43-2 

 None 

U109 10 

US-40 (Solvent) MSDS Not Found None 

Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012 K-17 
 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

APPENDIX K—HAZARDOUS MATERIALS MANAGEMENT SUMMARY
 

Product Hazardous Substances CAS# RCRA# RQ* (lbs) 

Valuprop Ceramic Propant Aluminum Silicate 1302-76-7 

Valve Flush None None 

Vanish Drop Ins 

Acid Blue #9 

Hydroxyethyl Cellulose 

Pine Oil 

Sodium Dodecylbenzene sulfonate 

Sodium Gluconate 

Sodium Sulfate 

Sodium Tetraborate Pentahydrate 

3844-45-9 

9004-62-0 

8002-09-3 

25155-30-0 

527-07-1 

7757-82-6 

1330-43-4 

None 1,000 

Versaprop (all mesh sizes) Aluminum Oxide 

Aluminum Silicate 

None 

None 

Versaset Sodium Aluminate 1302-42-7 

Vicon NF Breaker Chlorous Acid, Sodium Salt 

Sodium Chloride 

7758-19-2 

7647-14-5 

Water Finding Paste All Ingredients Non Hazardous None 

WD 40 Aerosol 

Aliphatic Petroleum Distillate 

Carbon Dioxide 

LVP Hydrocarbon Fluid 

Non-hazardous ingredients 

Petroleum Based Oil 

8052-41-3 

124-38-9 

64742-47-8 

None 

64742-65-0 

WG-17 Gelling Agent Cellulose derivative None 

WG-31 Gelling Agent Guar Gum 9000-30-0 

Windex, Blue 

Ethylene Glycol n-hexyl ether 

Isopropanol

Water 

112-25-4 

 67-63-0 

7732-18-5 

WLC-5 Fluid Loss Additive Complex Carbohydrates None 

Xylene Ethyl Benzene 

Xylene

100-41-4 

 1330-20-7 

None 

U239 

1,000 

100 

ZoneSealant 2000 Isopropanol 67-63-0 

ZoneSealant 3000 Keratins, Hydrolyzates 69430-36-0 

* Reportable Quantity 

K-18 Continental Divide-Creston Natural Gas Development Project Draft EIS  November 2012