# I 

# •

APPLICATION FORAN NSR PSD/TITLE V SYNTHETIC MINOR AIR QUALITYPERMIT PATRICIA CHARGING 2-158 PAD 

# OIL & 

# GAS

VCTI FACILITY

BisonEngineering, Inc. 1400 11th Avenue Helena, MT (406) www



# ... December,29;i11i ',':;:_-**-~.**



# - 

# -

# •

DAKOTA-3 E&P COMPANY, LLC 1\ subsidiaryorWllliams 1001 17111 Street, Suite 1200 Denver. CO80202 303/527-3900 

# DEC 29 

# 2011 

# 8P-AR December29, 20II
Ms. Kathleen Paser Duplicate submittal provided via e-mail to: MinorNSR PermittingCoordinator r8airpermitting@epa.gov 

# • U.S. EPA, Region 

### 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129 Re: Synthetic Minor Source Permit Application for the Patricia Charging 2-15H Pad Dear Ms. Paser: Dakota-3 E&P Company, LLC (Dakota-3) a subsidiary ofWilJiams is submitting this Synthetic Minor Source Permit Application for the Patricia Charging 2-15H Pad. This application is being submitted in accordance with the requirements ofFederal MinorNew Source Review Rule. Do not hesitate to contact me with any questions either by phone at 303-606·4056, or bye-mail at JoDell.Mizoue@Williams.com. Sincerely, 

### Williams Dakota-3E&P Company, LLC 

# /dJ(
JoDell Mizoue, P.E Staff'Environmental Specialist 

# •
Attachment cc: File Joe Gillies Jr. EnviromnentalDirector, Environmental Division, 204 W. Main, NewTown, NO 58763-9404 Tex Hall, Chairman Three Affiliated Tribes, 404 Frontage Road, New Town, ND 58763-9404 (letterOnly) 

# •

# • E. TABLE OFESTIMATED EMISSIONS The following tables provide the total emissions in tons/year for all pollutants from the calculations required in Section D ofthis form, as appropriate for the use specified at the topofthe form. 

### E(i)
- Proposed New Facility Pollutant


# • PM PM)o PM 15

SOl NOl CO VOC

Pb Fluorides

H2SO 4 H2S TRS RSC 

### Potential Emissions (tpy) 0.15 0.15 0.15 0.05 10.09 18.99 320.46 Negligible Negligible Negligible Negligible Negligible Negligible Proposed Allowable Emissions (tpy) 0.18 0.18 0.18 0.05 10.71 22.33 13.24 Negligible Negligible Negligible Negligible Negligible Negligible PM
- Particulate Matter PMlO - Particulate Matter less than 10 microns in size PM2.s
- Particulate Matter less than 2.5 microns in size SOx
- SulfurOxides NOx
- Nitrogen Oxides CO
- Carbon Monoxide VOC
- Volatile Organic Compound Pb
- Lead andlead compounds Fluorides
- Gaseous and particulates H2 S04 - Sulfuric Acid Mist H2S - Hydrogen Sulfide TRS
- Total Reduced Sulfur RSC - Reduced Sulfur Compounds


### Emissions calculations must include fugitive emissions ifthe source is one the following listed sources, pursuant to CAA Section 302(j): (a) Coal cleaning plants (with thermal dryers); (r) Sinteringplants; (b) Kraft pulp mills; (s) Secondary metal production plants; (c) Portland cementplants; (1) Chemical process plants (d) Primaryzinc smelters; (u) Fossil-fuel boilers (orcombinationthereof) totaling (e) Iron and steel mills; more than 250 million British thermal units per hour (f) Primary aluminum orereduction plants; heat input; 

# • (g) Primarycopper smelters; (v) Petroleum storage andtransfer units with a total (h)Municipal incinerators capable ofcharging more than storage capacity exceeding 300,000barrels; 250 tons ofrefuse per day; (w) Taconite ore processing plants; (i) Hydrofluoric, sulfuric, or nitric acid plants; (x) Glass fiber processing plants; (j) Petroleumrefineries; (y) Charcoal production plants; (k) Lime plants; (z) Fossil fuel-fired steam electric plants ofmore that (I) Phosphaterock processingplants; 250million British thermal units per hour heatinput, (m) Coke oven batteries; and (n) Sulfur recovery plants; (aa) Any other stationary source category which, as of (0) Carbon black plants (furnaceprocess); August 7, 1980, is being regulated under section I II or (p) Primarylead smelters; 112 ofthe Act. (q) Fuel conversion plants; 

# •

# • E(ii)
- Proposed New Construction at an Existing Facility orModification ofan Existing Facility This section ofthe application is not applicable. The application is for a new facility only. 

### Pollutant Current Actual Emissions (tpy) Current Allowable Emissions (tpy) Post-Change Potential Emissions (tpy) Post-Change Allowable Emissions (tpy) PM 

## N/A N/A N/A N/A PM)D 

## N/A N/A N/A N/A PM 2.5 

## N/A N/A N/A N/A**SO~** 

## N/A N/A N/A N/A**NO~** 

## N/A N/A N/A N/A

CO 

## N/A N/A N/A N/A voc 

## N/A N/A N/A N/A

Pb 

## N/A N/A N/A N/A NH3 

## N/A N/A N/A N/A Fluorides 

## N/A N/A N/A N/A

H2SO4 

## N/A N/A N/A N/A

H2S 

## N/A N/A N/A N/A TRS 

## N/A N/A N/A N/A RSC 

## N/A N/A N/A N/A 

# •

PM
- ParticulateMatter PM lO - Particulate Matter less than 10 microns in size PM2.5
- Particulate Matterless than 2.5 micronsin size SOx
- Sulfur Oxides NOx
- Nitrogen Oxides CO
- Carbon Monoxide VOC
- Volatile Organic Compound Pb
- Lead and lead compounds NH3
- Ammonia Fluorides
- Gaseous andparticulates H2S04 - Sulfuric Acid Mist H2S - Hydrogen Sulfide TRS
- Total Reduced Sulfur RSC
- Reduced Sulfur Compounds



# •

# • Instructions Use ofThis 

### Form
• Proposed new construction or modifications should first be evaluated to detennine ifthe change is major under the major NSRprogram using the procedures at 40 CFR 52.21 (i.e., baseline actual to projected actual applicability test). Ifthe proposed construction does not qualify as a major under that test, then it may

### be subject to the requirements ofthe minor NSR rule at 40 CFR49.151. 

### Helpful Definitions from the Federal Minor NSR Rule (40 CFR49)
- This is not a comprehensive list. 

# • 40 CFR 49.152(d)
- Modification means any physical or operational change at a source that would cause an increase in the allowable emissions ofthe affected emissions units for anyregulated NSR pollutant orthat would cause the emission ofanyregulatedNSR pollutant not previouslyemitted. The following exemptions apply: (1) A physical oroperational change does not include routine maintenance, repair, orreplacement. (2) 

### An increase in the hours ofoperationorinthe productionrate is not considered an operational change unless such increase is prohibitedunder any federally-enforceable permit conditionor other pennit condition that is enforceable as a practical matter. (3) A change in ownership at a source is not considered a modification.


### • 40 CFR 49.

### 152(d)
-Allowable emissions means "allowableemissions" as defined in §52.21(b)(16), except that the allowable emissions for any emissionsunit are calculated considering any emission limitations that are enforceable as a practical matter onthe emissions unit's potential to emit.
• 52.21 (b)( 

### 16)
-

### Allowable emissions means the emissions rate ofa stationary source calculated using the maximum rated capacity ofthe source (unless the source is subject to federally enforceable limits which restrict the operating rate, orhours ofoperation, orboth) and the most stringent ofthe foBowing: 

# • (i) The applicable standards as set forth in 40 CFRparts 60and 61; (ii) The applicable State Implementation Plan emissions limitation, including those with a future compliance date; or (iii) The emissions rate specified as a federally enforceable permit condition, including those with a future compliance date.



# • Page 7 of 15

# • A. General Facility Information I. Company Name 

### & Operator Name (ifdifferent): Provide the complete company and operator names. For corporations, include divisions or subsidiary name, ifany. 2. Facility Name: Provide the facility name. Please note that a facility is a site, place, location, etc... that may contain one or more air pollution emittingunits. 3. Type ofOperation: Indicate the generally accepted name for the operation (Le., asphalt plant, gas station, dry cleaner, sand & gravel mining, oil and gas wellsite, tank battery, etc.). 4. Portable Source: Does the facility operate in more than one location? Some examples ofportable sources include asphalt batch plants and concretebatchplants. 

### 5. Temporary Source: A temporary source, in general, would have emissions that are expected last less than 2 years. Do you expect to cease operations within the next 2 years? 

# • 6. NAICS Code: North American Industry Classification System. TheNAICS Code for your facility can be found at the following link**~** North American Industry Classification System (http://www.census.gov/epcd/naics/nsic2ndx.htm#Sl). 7. SIC Code: Standard Industrial Classification Code. Although the newNorth American Industry Classification System (NAICS) has replaced the SIC codes, muchofthe Clean Air Actpermitting processes continueto use thesecodes. The SIC Code for your facility canbefound at thefollowing link**~** Standard Industrial Classification Code (http://www.osha.gov/plslimis/sic manual.htrnl). 8. Physical Address: Provide the actual address ofwhere the facility is operating, not the mailing address. Includethe State and the ZIP Code. 9. Reservation: Provide the name oftheIndianreservation withinwhich the facility is operating. 10. County: Providethe County within which thefacility is operating. Ila & lIb. Latitude 

### & Longitude: These are GPS (global positioning system) coordinates. This information canbeprovided in decimal format ordegree-minute-second format. 12a 12d. Section-Township-Range: Pleaseprovide these coordinates in 114 SectioniSection/Township/Range. (e.g., SW Y4, NE Y4 IS36ITIONIR2IE). 

# •

Page 8 of 15 

# •

# • B. Current Permit Information Provide a list ofall permits that have been issued to your facility. This should include any Federal Minor New Source Review (MNSR), Prevention ofSignificant Deterioration (PSD) or NonAttainment New Source Review (NA NSR) permits, in addition to the most recent Part 71 permit. The permit number must be included with each permit identified. 

## C. Contact Information Please provide the informationrequested in full. 

### 1. Company Contact: List the full name (last, middle initial, first) ofthe owners ofthe facility orthe company contact. 

# • 2. Operator Contact: Provide the name ofthe operator ofthe facility ifit is different from the company contact. 

### 3. Facility Contact: The facility contact must be the local contact authorized to receiverequests for data and information. 4. ComplianceContact: The compliance contact must 

### be the local contact responsible for the facility's compliance with this rule. Ifthis is the same as the Facility Contact please note this on the form. 

## D. Attachments This section lists the information needed to complete the requested approval. This information should be accompanied by the supporting information listed on the form and described below. The information should be presented inenough detail to document how the facility is currently operating and/or how it is proposed to operate. ,f FORM SYNMIN Ifsynthetic minor limits arebeingrequested, we recommend that the information from checklist tiled Form 

### SYNMIN be included with this application. ,f Narrative description ofthe proposed production processes. 

# • 1. The narrative description should follow the flow ofthe process flow diagramto be submitted with this application. This needs to be as comprehensive as possible tohelp in understanding the proposed facility and how it will be operated. For example: What are the raw materials? What are the properties ofthe rawmaterials? Does the production process include heating, drying, the application ofchemicals, etc? How will the raw materials be affectedbythis process? What are the out puts from each step ofthe process (Le., crushed ore, dry gas, water, etc...)? Etc.... 2. The proposed operating schedulepresented in terms ofhours per day, days perweek, and weeks peryear. 3. A list ofthe type and quantity offuels and/orraw materials used. Each fuel andraw material should be described in enough detail to indicate its basic chemical components. 

# • Page 9 of 15

# • ,f A process flow chart identifying all proposed processing, combustion, handling, storage, and emission control equipment (include the unit identification # or code). This flow chart should illustrate the detailed narrative description requested above. 

### ./ List and describe all proposed units, emission units and air pollution-generating activities. At a minimum, provide the following: 1. The hourly, daily and annual maximum operating rates for each operating unit, production process, and activity. 2. The hourly, daily and annual maximum firing rates for each fuel and combustion equipment. 3. The capacity for storage units and the hourly, daily and annual maximum throughput ofmaterial in the storage units. 4. Material and product handling equipment and the hourly, daily and annual maximum throughput ofmaterial and product. S. Tank designs, tank storage capacities, hourly, daily and annual maximumthroughput 

# • ofmaterial and product. ,f Type and quantity offuels, including sulfur content offuels, proposedtobeusedona daily, annual and maximum hourly basis. ,f Type and quantity ofraw materials used or final productproduced proposedtobeused ona daily, annual and maximum hourly basis. ,f Proposedoperating schedule, including number ofhours per day, number ofdays perweek and number of weeks per year. ,f 

### A list and description ofall proposed emissioncontrols, control efficiencies, emission limits, and monitoring for each emissionunit and air pollution generating activity. 

### 1. Include manufacturer specifications and guarantees for eachcontrol device.



# .,

Page 10 of15 

# •

# • Criteria PollutantEmissions Estimates ./ Estimates ofCurrent Actual Emissions, Current Allowable Emissions, Post-Change Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants: particulate matter, PMJO, 

### PM2 .5, 

### sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead compounds, ammonia (NH3), 

### fluorides (gaseous and particulate), sulfuric acid mist (H2S04), hydrogen sulfide (H2

### S), total reduced sulfur (TRS) and reduced sulfur compounds, including all calculations for the estimates. I. These estimates are to be 

### made for each emission unit, emission generating activity, in addition to total emissions. 

# • 2. The information should include all ofthe supporting calculations, assumptions and references. Emission estimates must address all emission units and pollutantsproposed and/or affected by the limitation and be presented in short term (e.g. pounds per hour) as well as annual (tons per year) units. 3. Any emission estimates submitted to the Regional Administrator must be verifiable using currently accepted engineering criteria. The following procedures are generally acceptable for estimating emissions from air pollution sources: • Source-specific emission tests; • Mass balance calculations; • Published, verifiable emission factors that are applicable to the source. (Le. manufacturer specifications) • Other engineering calculations; or • Other procedures to estimate emissions specifically approved by the Regional Administrator. 4. 

### Guidance for estimating emissions can be found at http://www.epa.gov/ttnlchief/efuac/index.html. Current Actual Emissions: Current actual emissions for apollutant is expressed in tpy and generally is calculated by multiplying the actual hourly emissions rate in pounds perhour (lbs/hr) times actual hours operated (which is the number ofhours in ayear) and dividing by 2,000 

### (which is the number ofpounds in a ton). 

# • 1. For an existing airpollution source (permitted and unpermitted) that operatedprior to the application submittal, the current actual emissions are the actual rate ofemissions for the preceding calendaryear and mustbecalculatedusing the actual operatinghours, production rates, in-place control equipment, and types ofmaterials processed, stored, orcombusted during the preceding calendaryear. The emission estimates must bebasedupon actual test data or, in the absence ofsuch data, upon procedures acceptable to the Regional Administrator. Current Allowable Emissions: Current allowable emissions for apollutant is expressed in tpy and generally is calculated by mUltiplying the allowed hourly emissions rate in pounds per hour (Ibs/hr) 

### times allowed hours (which is the number ofhours in a year) and dividing by 2,000 

### (which is the number ofpounds in a ton). 

### 1. "Allowed" means the source is restricted by permit conditions that limit its emissions and are enforceable as apractical matter (i.e., allowable emissions). The allowable emissions for any 

# • Page II of 15

# • emissions unit are calculated considering any emissions limitations that are enforceable as a practical matter on the unit's PTE. 2. For an existing permitted air pollution sourcethat operatedprior to the application submittal, the current allowable emissions are the allowable rate ofemissions for the preceding calendaryear and must be calculated using the permitted operating hours, production rates, in-place control equipment, and types ofmaterials processed, stored, or combusted during the preceding calendaryear. 

### 3. For an existing airpollution source that does not have an established allowable emissions level prior to the modification must report the pre-change uncontrolled emissions. Post-Change Potential Emissions (Potential uncontrolled emissions from proposed project): This is the maximum capacity ofa source to emit a pollutant under its physical and operational design. This is expressed in tpy and generally is calculated by multiplying the maximum hourly emissions rate in pounds per hour (lbs/hr) times 8,760 hours (which is the number ofhours in a year) and 

# • dividing by 2,000 (which is the number ofpounds in a ton). Post-Change Allowable Emissions: A source's allowable emissions for apollutant is expressed in 

### tpy and generally is calculatedby multiplying the allowed hourly emissions rate in poundsperhour (lbs/hr) 

### times allowed hours (which is the number ofhours in a year) and dividing by 2,000 (which is the number ofpounds in 

### a ton). L 

### Unless the source is restricted by permit conditions or other requirements that are enforceable as a practical matter, the post-change allowable emissions would be equivalent to post-change uncontrolled emissions. For the post-change allowable emissions a lower level ofallowable emissions may be proposed. 2. For physical or operational changes at minor sources and for minor physical or operational changes at major sources, the total increase in allowable emissions resulting from your proposed change would be the sumoffollowing: • For each new emissions unit that is to be added, the emissions increase would be the potential to emit ofeach unit. • For each emissions unit with an allowable emissions limit that is to be changed or replaced, the emissions increase would be the allowable emissions ofthe emissions unit after the change or replacement minus the allowable emissions prior to the change or replacement. However, this may not be a negative value. Ifthe allowable emissions ofan 

# • emissions unit would be reduced as a result ofthe change or replacement, use zero in the calculation. • For each unpermitted emissions unit (Le., a unit without any emissions limitations before the change) that is to be changed or replaced, the emissions increase would be the allowable emissions oftheunit after the change orreplacement minus the potentialto emit prior to the change or replacement. However, this may not be a negative value. Ifthe allowable emissions ofan emissions unit would be reduced as a result ofthe change or replacement, use zero in the calculation.

Page 12 of 15 

# •

# • ./ Modeling Analysis Do I need to do a modeling analysis? The Federal Minor New Source Review Regulations at 40 CFR 49.1S9(d) requires that a modeling analysis (AQIA) ofproposed emissions be performed ifthere is reason to be concerned that new constructionwould cause or contribute to a National Ambient Air Quality Standard (NAAQS) or Prevention ofSignificant Deterioration (PSD) increment violation. In addition, ifthe AQIA reveals that the new construction could cause orcontribute to a NAAQS or PSD increment violation; such impacts must 

### be reduced before a pre-construction permit can be issued. To facilitate the protection ofthe NAAQS and PSD Increment, EPA Region 8 requests that those 

# • proposed activitiesthat meet the following criteria performan AQIA: 1. The proposed activity has air emissions that EPA Region 8 determines have the potential to cause adverse air quality effects for which an air quality impact analysis is necessary for an accurate assessment ofthe environmental impact ofthe activities proposed. 2. Modeling ofproposed emissions is usually warranted, even though the proposed activity does not meet the modeling requirements, above, ifit is reasonable to believe the new activity may cause orcontribute to a violation ofapplicable ambient air quality standards orincrements in circumstances such as: (a) A substantialportion ofthe new ormodified emissions have poor dispersion characteristics (e.g., rain caps, horizontal stacks, fugitive releases, or

### buildingdownwash) in close proximity to 

### ambientair at the site boundary; (b) The new ormodified emissions are located in 

### complexterrain (e.g., terrain above stack height in close proximity to the source); or (c) The new ormodified emissions are located in areas with existing air quality concerns. 

# • (d) 

### Ifyou have questions about whether modeling may be necessary based onthe 4th criteria above, please contact EPARegion 8'sModeling Lead: Gail Tonnesen Region 8 Modeling Lead Tonnesen.gail(w,epa.gov 

### 303-312- 6113



# • Page J3 of 15

# • What Kind ofAir Quality Modeling Analysis Is Needed? I. EPA Region 8 considers a stepped or phased approach to modeling to be appropriate, as follows: Step I: Qualitative Air Quality Assessment Step 

### 2: Screening Modeling Analysis Step 3: Preliminary Modeling Analysis (refmed modeling) Step 4: Full Impact Modeling Analysis (refmed modeling) Step 5: PSD Increment and NAAQS Analysis Step 6: Additional Impact Analysis 2. Step I: Qualitative Air Quality Assessment 

# • Narrative description ofthe current air quality conditions and the expected impact the permitted source wouldhave on that air quality. Some suggested factors to consider in the qualitative discussioncould include meteorology, terrain, distance to ambient air, expected emissions, etc. Ifa convincing case cannot be made qualitatively that no impacts to air quality would be expected, a screening analysis should next be performed. 3. Step2: Screening Analysis Forproposed new ormodified sources that meet the modeling requirement criteria identified above, protection ofair quality fromproposed emissions maybe shownbyusing a simple screening technique (e.g., SCREEN3 or AERSCREEN). Screening models are available for download at the EPA SCRAM website: http://www.epa.gov/ttn/scramldispersionscreening.htm. A pre-approved modeling protocol is not necessarypriorto conducting a Screening Analysis. 4. Ifthe proposed new ormodified emission increases do not increase ambient concentrations ofa pollutant by more thanthe significant impact levels, as compared to the SILs identified below, no further modeling is necessary. 

### S'



### 19m 'fi



### leant I

### mjJact 

### Leve s 

### I 

# , 

# •

I 

### Pollutant Averaging Period Class II Area SIL (uwm3 ) Class IArea SIL (uWm3) S02 1hr 3 ppb or 7.8 ug/m> (interim) 

### ---... 3hr 25 1.0 24 hr 5 0.2 Annual 1 0.08 

### PM2.5 24 hr 0.07 1.2 Annual 0.06 0.3 

## I PM 10 24 hr 5 0.2 Annual 1 0.08 

### N02 I hr 4 ppb or 7.5 ug!m' (interim) ---­ Annual I 0.08 

### CO 1hr 8 hr 2,000ppb 500ppb Note: The Class I area SILs areprovided as guidance and have not been formalized by EPA.
Page 14 of)5 

# •

# • 5. Sources that cannot demonstrate protection ofair quality using a screening technique should continue to the modeling requirements in

### Step 3 through 

### Step 6. Modeling in Steps 3 through 6 should be performed based an approved protocol. 6. Applicants are encouraged to contact the EPA Region 8 Modeling Lead priorto conducting any refined modeling analysis (Step 3 through Step 6) to obtain an approved protocol. 

## What Should I Include In My Application IfModeling Is Necessary? 1. Approved Modeling Protocol In orderto expedite the permitting process, it is recommended that you include a protocol that has already been approved. 

### An application will not be deemed complete untilthe protocol has been approved. 

# • 2. Modeling Results 

### In all cases, the modeling results should include the name ofthe modelused, all input parameters, and the resulting output. Electronic copies ofthe modeling input/output files should be provided to EPARegion 8 . 

# ./ ESA The Endangered Species Act requires us, in consultation with the U.S. Fish and Wildlife Service andlor the NOAAFisheries Service, to ensure that actions we authorize are not likely tojeopardizethe continued existence ofany listed species orresult in the destruction oradverse modification of designated critical habitat ofsuch species. To expedite the approval ofyour proposed construction, we encourage you to identify any listed species that you may bereadily aware ofthat could be affected byyourproposal. The following website has beenprovided to assist you: http://www.fws.gov/endangeredl Simply enterthe State and County in which you proposeto construct to obtain a general listing. 

# • ./ NHPA TheNational Historic Preservation Act requires us, in consultation with State andlor Tribal Historic Preservation Officers to ensure that actions we authorize are not likely to affect culturalresources. To expedite the approval ofyour proposed construction, we encourage you to identify any cultural resources that you may be readily aware ofthat could be affected byyourproposal. The following website has beenprovided to assist you: 

### 1:!t1p;/ Inrlm.focus.nps.gov /patreghome.do?searchtype=natreghome Simply enter the State and County in which you proposeto construct to obtain a general listing. 

# • Page 15 ofl5

# • UNITED STATES ENVIRONMENTAL PROTECTION AGENCY Region 8 Air Program FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

## Checklist
- Synthetic Minor Limit Request (Form SYNMIN) Use ofthisinformation request form is voluntary and notyet approved by the Office ofManagement and Budget. The following is a check list ofthe type ofinformation that Region 8 will use toprocess information on your proposed project While submittal ofthis form is notrequired, it does offer details on the information wewill use to complete your requested approval and providing theinformation requested mayhelp expedite the process. Useofapplication forms for thisprogram is currently under Office ofManagement and Budget review and these information request forms will be replaced/updated after thatreview is completed. Please submitinformation to fo))owing two entities:

Company Name Dakota-3 E&P Company, LLC Facility Name Patricia Charging 2-15H Pad Company Contactor OwnerName JoDell Mizoue Title StaffEnvironmental Specialist Mailing Address 1001 I

### i h Street, Suite 1200 Denver, CO 80202 Email Address JoDell.Mizoue@Williams.com TelephoneNumber (303) 606-4056 FacsimileNumber (303) 692-8285 The Tribal Environmental Contact for the specific reservation: 

# • Ifyou need assistance 

### in identifying the appropriate Tribal Environmental Contact and address, pleasecontact the EPA Region 8 Tribal 

### Air Coordinator: Alexis North, EPA Region 8 Tribal Air Coordinator 303-312-7005 north.alexis@epa.gov



# • Foreach criteria airpollutant,hazardous airpollutant and for all emission units and airpollutantgenerating activities to be covered by a limitation, include the following: ../ Item 1 - Theproposed limitation and a description ofits effect on current actual, allowable and thepotential to emit. ../ Item2 - The proposedtesting, monitoring, recordkeeping, and reporting requirements to beused to demonstrate and assure compliance withtheproposed limitation. ../ Item3 - A description ofestimated efficiencyofair pollution control equipment underpresent or anticipated operating conditions, including documentation ofthe manufacturer specifications and guarantees. ../ Item4 - Estimates ofthe Post-Change Allowable Emissions that would result from compliance with the proposed limitation, including all calculations for the estimates. ../ Item 5 Estimates ofthepotential emissions ofGreenhouseGas (GHG) pollutants before and after proposed emission controls. Federal Minor NSRPermit Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129



### A. GENERAL INFORMATION

B. ATTACHMENTS

# • Instructions Use this form to provide general and summary information about the synthetic minor NSR source (facility orplant) on Tribal lands and to indicate the emissions limitations requested. Submitthis form once, in addition toFORM NEW, for each synthetic minorNSR source on Triballands. 1. 

### Who Can Request Federally-EnforceableLimitationsUnderthe Tribal NSR Authority? The Tribal NSR Rule applies onlyto sources located within the exterior boundaries ofanIndian reservation inthe United States ofAmerica orother lands as specified in 40 CFRpart 49, collectively referred to as "Indiancountry". So, to use the authority in the Tribal NSR Rule to create federally­ 

# • enforceable limitations, a facility must be located within Indian country. Land ownership status (for example, whether the land is owned by a Tribal member orwhether the land is owned in fee or in trust) does not affect how the rule applies. 

### 2. Who Might Wantto Request Federally-EnforceableLimitations? Theprimaryreason for requesting federally-enforceable limitations is to avoid an otherwise applicable federal CleanAir Act program, rule orrequirement. Many federal Clean Air Act programs use a source's "potential to emit" (PTE) air pollutionto determine which rules orrequirements apply. A facility's PTE is based onthe maximum annual operational (production, throughput, etc) rate ofthe facility taking into consideration the capacity and configuration ofthe equipment and operations. Emission or operational limits can also betaken into consideration as maximums ifthey are federally enforceable. So, using a synthetic minor NSR permit to establish federally enforceable limitations can lower a facility's PTE and possibly allow the facility to avoid certain federal Clean Air Act requirements. Three examples offederal Clean Air Act programs that use PTEto determine whether they apply are 

# • (I) the Prevention ofSignificant Deterioration (PSD) constructionpermittingprogram, (2) the Title V operating permit program, and (3) the Maximum Achievable ControlTechnology (MACT) program. For example, existing sources that are considered "major" for Title V (meaning they have the potential to emit air pollution at levels defmed in that rule as "major") must apply for a Title V operatingpermit. Ifa source accepts a federally-enforceable limitation through a synthetic minor NSRpermit that reduces their PTEto below the "major" threshold, andthe source does not meet anyofthe other requirements that would trigger applicability to the part 71 program, thenthe source no longer needs a Title V operating permit. When planning for the construction ofa new source orexpansion ofan existing source, a source can also accept limitations on PTE (using a synthetic minor NSR permit) that allow the source to avoid PSD. Limitations on PTE can similarlyhelp a source to avoid new MACT standards that would otherwise apply to the source. 

### 3. Section B. ATTACHMENTS This section lists the information that must be attached to the application form for each requested limitation. The requested limitation(s) must be described for each affected emissions unit (orpollutantgenerating activity) and pollutant and must be accompanied bythe supporting information listed onthe form and described below. Note that applicability ofmany federal CleanAir Act requirements (such as Title V, PSD and MACT) is often based on facility-wide emission levels ofspecific pollutants. Inthat 

# • Page 2 of4

# • case, all emissions units at a facility and all pollutants regulated by that given rule orregulation must be addressed by this section ofthe application form. 

### Item 1
- The requested limitation and its effect on actual emissions orpotential to emit must be presented in enough detail to document how the limitation will limit the source's actual orpotential emissions as a legal and practical matter and, ifapplicable, will allow the source to avoid anotherwise applicable requirement. The information presented must clearly explain how the limitation affects each emissionunit and each air pollutant from that emission unit. Use the informationprovided inresponse to Item4 below to explain how the limitation affects emissions before and after the limitation is in effect. 

### Item 2
- Foreach requested limitation, the application must include proposed testing, monitoring, recordkeeping and reporting that will be used to demonstrate and assure compliance with the limitation. Testing approaches should incorporate and reference appropriate EPA reference methods where applicable. Monitoring should describe the emission, control orprocess parameters that will be relied on and should address frequency, methods, and quality assurance. 

### Item 3 - The application must include a description and estimated efficiency ofairpollutioncontrol equipment underpresent or anticipated operating conditions. For control equipment that is not proposed to be modified to meet the requested limit, simply note that fact; however, for equipment that is proposed to be modified (e.g. improved efficiency) ornewly installed to meet theproposed limit, address both current and future descriptions and efficiencies. Include manufacturer specifications and guarantees for each control device. 

### Items 4
- Any emission estimates submitted to the Regional Administratormust 

### be verifiable using currently accepted engineering criteria. The following procedures are generally acceptable for estimating emissions from air pollution sources: (i) Source-specific emissiontests; (ii) Mass balance calculations; (iii) 

### Published, verifiable emission factors that are applicable to the source. (Le., manufacturer specifications). 

### (iv) Other engineering calculations; or (v) Otherprocedures to estimate emissions specifically approved by the Regional Administrator. Post-Change Allowable Emissions: A source's allowable emissions for a pollutant is expressed in tpy and generally is calculatedby multiplying the allowed hourly emissions rate in pounds perhour (lbslhr) times allowed hours (which is the number ofhours in a year) and dividing by2,000 (which is the number ofpounds in a ton). 

### Item 5 - New constructionprojects that have the potential to emit GHG emissions ofat least 100,000 tpy C02 e and 100 or250 tpy on a mass basis, modifications at existing PSD facilities that increase GHG emissions by at least 75,000tpyC02e and minor sources that increase GHG emissions byat least 100,000tpy C02e and 100 or 250 tpyon a mass basis are subject to PSD permitting requirements, even ifthey do not significantly increase emissions ofany otherpollutant. As such, anyrequested limits to avoid PSD must take into account greenhouse gases. Therefore, please include in yourpermit application estimates ofthe potential emissions ofthe following pollutants before and after proposed emission controls. More information about GHG permitting and how to calculate C02 equivalents (C02e), the mass emissions ofeach individual GHG 

# •



# •

Page 3 of4 

# •

# • adjusted for its Global Warming Potential (GWP) can be found at: http://epa.gov/nsr/ghgdocs/ghgpermittingguidance.pdf 1. Carbon dioxide (C02 ) 

### 2. Methane (CH4) 

### and its C02e 3. Nitrous oxide (N2 0) and its C02 e 4. Hydrofluorocarbons (HFCs) and its C02e 5. Perfluorocarbons (PFCs) and its C02e 6. Sulfur hexafluoride (SF6) 

### and its C02e 

# •



# •

• Page 4 of4

# • PATRICIA CHARGING 2-15H PAD ATTACHMENTS: Attachment A: Application Report Attachment B: Emission Inventory Attachment C: Flashing Emissions Calculations Attachment D: Representative Low Pressure Oil Analytical Data Attachment E: Representative Gas Analysis Attachment F: Engine Manufacturer's Specs Attachment G: Emission Control Device Manufacturer's Specs Attachment H: Process Flow Diagram of Facility Attachment I: Production Decline Curve Calculations Attachment

## J: Diesel Tank EPA TANKS 4.09d Emission Summary


# •

Dakota-3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324

# ATTACHMENT A: APPLICATION REPORT



# •



# •

Dakota-3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324

# • C. CONTACT INFORMATION



# •



# • Company Contact: JoDell Mizoue 

# I Title:

. StaffEnvironmental i Specialist Mailing Address: 1001 171n Street, Suite 1200 Denver, CO 80202 Email Address: JoDell.Mizoue@WiIliams.com Telephone Number: (303) 606-4056 Facsimile Number: (303) 692-8285 Operator Contact (ifdifferent from company contact): Same as above Title Mailing Address Email Address Telephone Number Facsimile Number Facility Contact: Same as above Title Mailing Address Email Address Telephone Number Facsimile Number Compliance Contact: Same as above Title
i Mailing Address Email Address Telephone Number Facsimile Number



# •

# • D. ATTACHMENTS Include all ofthe following information (see the attached instructions) ../ FORM SYNMIN
- New Source Review Synthetic Minor Limit Request Form, ifsynthetic minor limits are beingrequested. ../ Narrativedescription ofthe proposed productionprocesses. This description should follow the flow of the process flow diagramtobe submitted with this application. ../ Process flow chart identifying all proposed processing, combustion, handling, storage, and emission control equipment. ../ A list and descriptions ofallproposed emissionunits and air pollution-generating activities. ../ Type and quantity offuels, including sulfur content offuels, proposed to beused on a daily, annual and maximum hourly basis. 

# • ../ Type and quantity ofraw materials used or final product producedproposed to beused on a daily, annual and maximum hourly basis. ../ Proposed operating schedule, including number ofhours per day, number ofdays per week and number of weeks per year. ../ A list and description ofall proposed emission controls, control efficiencies, emission limits, and monitoring for each emissionunit and air pollution generating activity. ../ Criteria PollutantEmissions
- Estimates ofCurrent Actual Emissions, Current Allowable Emissions, PostChange Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants: particulate matter, PMJO, PM2,5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead compounds, fluorides (gaseous and particulate), sulfuric acid mist (H2S04), hydrogen sulfide (HzS), total reduced sulfur (TRS) and reduced sulfur compounds, including all calculations for the estimates . ../ These estimates are to bemade for each emission unit, emission generating activity, and theproject/facility in total. ../ Modeling
- Air Quality ImpactAnalysis (AQIA) ../ ESA (Endangered Species Act) 

# • ../ NHPA JNational HistoricPreservationAct)



# •

# •

• APPLICATION FORAN NSR PSD/TITLE V SYNTHETIC MINOR AIR QUALITY PERMIT PATRICIA CHARGING 2-15H PAD OIL & 

# GAS PRODUCTION FACILITY

Prepared for: 

## Dakota-3 E&P Company, LLC 1001 17th 

## Street, Suite 1200 

## Denver, CO 80202

Preparedby: 

# • Bison Engineering, Inc. 1400 11th 

## Avenue Helena, MT 59601 (406) 442-5768 www.bison-eng.com



## December 29, 2011

# • TABLE OF CONTENTS 1.0 INTRODUCTION
.................................................................................................. 1 1.1 Summary
................................................................................................... 1 1.2 Site Location
.............................................................................................. 1 1.3 Site Description
.......................................................................................... 1 2.0 NARRATIVE DESCRiPTION
................................................................................2 3.0 POTENTIAL TO EMIT ESTIMATE
.......................................................................4 3.1 Production Storage Tank VOC Emissions
................................................. 7 3.2 Produced Casing Head Gas Emissions
..................................................... 7 

# • 3.3 Reciprocating Intemal Combustion or Compression Ignition Engines
....... 8 3.4 Natural Gas External Combustion Unit Emissions
..................................... 8 3.5 Truck Loading Emissions
...........................................................................8 3.6 Fugitive Emissions: Dust and Equipment Leaks
....................................... 8 4.0 EMISSIONS AND OPERATIONAL LIMITS REQUESTS
..................................... 9 4.1 Production Storage Tank Emissions
.......................................................... 9 4.2 Reciprocating Intemal Combustion or Compression Ignition Engines
....... 9 5.0 ALLOWABLE EMiSSiONS
................................................................................. 10 5.1 Storage Tank Emissions
.......................................................................... 10 5.2 Produced Casing Head Gas Emissions
................................................... 10 5.3 Rice Engine Emissions
............................................................................ 10 5.4 Natural Gas External Combustion Unit Emissions
................................... 10 5.5 Truck Loading Emissions
......................................................................... 11 5.6 Fugitive Emissions: Dust and Equipment Leaks
..................................... 11 5.7 Diesel Storage Tank Emissions
............................................................... 11 6.0 PROPOSED MONITORING AND RECORDKEEPING
...................................... 12 6.1 Production Storage Tanks
....................................................................... 12 6.2 Production Storage Tank Emissions Control Device
............................... 13 6.3 

# • 6.4 Produced Casing Head Gas Emergency Utility Flare Rice Engines
............................................................................................

.............................. 15 16 6.5 Natural Gas-Fired External Combustion Units
......................................... 16 6.6 Truck Loading
.......................................................................................... 17 6.7 Fugitive Emissions: Dust and Equipment Leaks
..................................... 17 6.8 General Recordkeeping Requirements
.................................................... 19 7.0 QUALITATIVE AIR QUALITY ASSESSMENT
.................................................... 20 8.0 ENDANGERED SPECIES ACT
..........................................................................21 9.0 NATIONAL HISTORIC PRESERVATION ACT
..................................................22
Patricia Charging 2-15H Pad 12/29111 pg. ii NSR Synthetic Minor Permit Application Project#: WEP211324

# • FIGURES Figure 1: Example of Maximum PTE from a Seven Well Pad
................................... 5 Figure 2: Example of Actual Production from a Seven Well Pad
.............................. 6 

## ATTACHMENTS Attachment A: Attachment B: Attachment C: Attachment D: Attachment E: Attachment F: Attachment G: Attachment H: Attachment I: Attachment 

### J: Application Report Emission Inventory Spreadsheets E&P Tank V2 Emission Summary Output Representative Low Pressure Oil Analytical Data Representative GasAnalysis 

# • Engine Manufacturer's Specs Emission Control Device Manufacturer's Specs Process Flow Diagram of Facility Production Decline Curve Calculations Diesel Tank EPATANKS 4.09d Emissions Summary



# •

Patricia Charging 2-15H Pad 12/29111 pg. iii NSR Synthetic Minor Permit Application Project#: WEP211324

# • 1.0 INTRODUCTION 1.1. Summary Dakota-3 E&P Company, LLC (Dakota-3) is submitting this application for a Prevention of Significant Deterioration (PSD) and/or Part 71 Title V (Title V) synthetic minor permit to the Environmental Protection Agency (Agency) in accordance with the Federal Minor New Source Review (NSR) Rule (40 CFR 49) adopted pursuant to the Federal Clean Air Act. 

# • Dakota-3 is proposing to construct and operate the Patricia Charging 2-15H Oil and Gas (O&G) production facility on the FBIR. Included in this application for a synthetic minor permit are allowable emissions speCified by requested federally enforceable permit conditions that limitthe emissions from the facility to below the PSD and/orTitle V major source thresholds. These limits can be found in Section 4.0 ofthe application. 

## 1.2. Site Location The Patricia Charging 2-15H Pad is proposed to be located in the northwest % of the northeast % Section 15, Township 149 North. Range 93 West, Dunn County, on the FBIR in North Dakota. 

## 1.3. Site Description At the proposed Patricia Charging 2-15H Pad there will be two oil and gas wells that are proposed to produce to the facility. The facility will be situated on an approximately ten acre site, with an elevation of approximately 2,000 feet (mean sea level), in Dunn County, North Dakota. The surrounding area is mainly used for agriculture and livestock grazing. The proposed pad's associated well names are: 1. Patricia Charging 2-15HC 2. Patricia Charging 2-15HD 

# • The names of the wells may be subject to change due to landowner requirements, drilling location changes, timing of well leases, etc. The Agency will be notified if the names change.

Patricia Charging 2-15H Pad 

### pg. NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 2.0 NARRATIVE DESCRIPTION This section of the application provides a detailed description of the operations at the Patricia Charging 2-15H Pad. For purposes of estimating emissions from this facility, the combined first twelve-month potential production from the two proposed wells at this facility was used. These production rates can be found in Attachment B, Emission Inventory. The production rates used in this application are grossly overestimated when compared to the actual predicted production rates in the first and subsequent years. The wells that will be producing to this facility do not begin producing at the same time. In reality, there will be up to six or more years' difference in when the initial production from wells begin to when the final wells are constructed and begin to produce. It is not physically possible 

# • for all of the wells to be simultaneously drilled and begin initial production. However, to allow for reasonable flexibility and to be conservative, this application has considered a maximum potential production case from the pad. Due to ever-changing drilling schedules, completion schedules, economics, etc., the wells will begin actual production at different times. The entire pad facility will consist of the following primary production equipment and capabilities. 2 - Heater Treater/Separators 2 - Line-Heaters (0.75 MMBtu/hr max) 8 - Oil Production Tanks 1 - Gasoline Recycling Pump 2 - Produced WaterTanks 2 - Electric Lifting Units 2 - Oil and Gas Producing Wells 1 - Truck Loading Rack 1 - Manufactured Produced Gas Flare 2 - Diesel Engines 1 - Manufactured Enclosed Tank Vapor Combustor 

### The oil/gas/water emulsion being produced from the wells is transported up each wellbore using an electric lifting unit. The emulsion from the wells producing to this site is transported in a closed system to individual two-phased separators and then to the three-phase separators (heater treaters). The initial two-phase separator reduces the pressure of the oil/gas/water emulsion to allow the gas to separate from the oil and water. The heater treaters then reduce the pressure closer to ambient pressure and heat the leftover emulsion using a flame-arrested line-heater. The combination of higher 

# • temperatures and low pressures allow for additional separation of the gas/oil/water phases from each other because ofdifferences in densities. The line-heater is fueled by onsite produced casing head gas that is routed to the heater's combustion chamber. Propane may also be used as an alternative fuel if necessary. Following the heater treater the oil and water are routed to their separate storage tanks. The produced casing head gas is transferred from the two-phase separators to the sales gas pipeline. An onsile utility flare serves as an emergency backup in the event that the gas cannot be placed into the sales line. The oil and water production tank's working, standing, breathing, and flashing vapors are routed to an enclosed combustion 

# • Patricia Charging 2·15H Pad 12/29111 pg.2 NSR Synthetic Minor Permit Application Project#: WEP211324

# • device. The stored oil is typically transported for sale via the Lease Automated Custody Transfer (LACT) unit, with the truck loadout serving as an emergency backup if there was a malfunction with the oil pipeline. Produced water is stored in the onsite water storage tank until it is transported offsite using the water pipeline. At the facility, there is a small gasoline fueled pump located near the production storage tanks. This pump is commonly known as a "transfer" or "recycle." The pump is used to periodically recycle the liquids (oil/water) in the bottom of the production tanks back into the heater treater for further separation. Otherwise. the facility is completely electrified; however. the electricity lines have not yet been installed at the facility. Onsite diesel genset engines will provide electricity until transmission lines are installed. 

# • A process flow diagram and plot plan ofthe site is shown in Attachment H.



# •

Patricia Charging 2-15H Pad 12/29/11 pg. 3 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 3.0 POTENTIALTO EMITESTIMATE In estimating the average production for the first twelve months, a decline curve was developed. The decline curve takes into account the fact that the initial production ofthe well will greatly decline over the initial twelve months of production. Assuming that each well's production would be equivalent to the initial production will grossly overestimate production and is not realistic for how an oil and gas well operates. The decline curve calculated for this facility was developed using existing well data from wells previously drilled and producing in the same region. The confidential decline curve estimations are included in Attachment I of the application. As noted in Section 2.0 above, determination of potential emissions from the proposed Patricia Charging 2-15H Pad has been approached in a very conservative fashion. The combined production rate for the pad assumes all of the wells start production simultaneously (represented in example Figure 1). With this assumption, the initial 30­ day production from each well is summed to estimate a potential total production rate from the pad. Operating practice is that the wells will be drilled over time, often months or even years apart. Further, after each well is drilled and brought into production, the initial production rate generally decreases greatly before the next well is drilled. Therefore, this potential to emit (PTE) estimate is meant only to define an outer envelope of emissions for permitting applicability purposes. Furthermore, the allowable emissions estimates presented in Section 4 are also very conservative compared to anticipated actual emissions that could be emitted at the facility during any given 12­ month rolling average. An example demonstrating the predicted production of a theoretical multiple well pad over an extended period of time is presented in Figure 2. This example does not represent predicted production from the well pad being permitted in this application; however, it does serve to demonstrate typical operations for this type offacility. 

# •

•

Patricia Charging 2-15H Pad 12/29/11 pg.4 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 

# • •

•

• ••••••••••••••• 

# •
Figure 1: Example ofMaximum PTE from a Seven Well Pad 

# Exam of Maximum PTE from a Seven Well Pad 6,000 

### •**~II** 

### seven wells begin production 5,000 

### simultaneously 

# • R'OOO**~ ~**  

# ., 

# • J,ooo -+­ • Total Production from Seven Wells on Pad 

# f +.­ :1,000 

# •

# .......**I--**

# ------------~~:.~.~.~.~.~~~~~~~~-- 1,000 •


## o 

## o 10 20 30 

### 40 Month

Patricia Charging 2-15H Pad 12129/11 pg.5 NSR Synthetic Minor Pennit Application Project #: WEP211324

# • • 

# • 

# • Figure 2: Example ofActual Production from a Seven Well Pad 

# Example ofActual Production From a Seven-Well Well Pad 3,500 

# II 6th and 7th wells begin production 3,000
2,500 Q Go 

## i GI 2,000 

# ! 

# S 5th well begins production

2nd well begins production 1st well begins production ""-Total Production from Seven Wells on Pad -12-Month RollingAverage Oil Production**~** 

### ii 1,500 c -12-Month RollingAverage Oil Production Limit

### ~ 1,000

500



### o 

## o 5 10 15 20 25 30 35 40 Month Patricia Charging 2-15H Pad 12129111 pg.6 NSR Synthetic Minor PermitApplication Project #: WEP211324

# •
Potential emissions from this facility originate primarily from the heater treater lineheaters emissions, the production storage tank uncontrolled emissions, truck loading emissions, diesel genset emissions, and fugitive emissions (e.g., truck loading, equipment leaks and road dust). The maximum design capacity of the engines and natural gas-fired external combustion units, in conjunction with maximum annual anticipated oil and gas production rates of this facility, were used in determining the facility's potential to emit (PTE). The oil, gas, and water production rates were estimated by using data from recently drilled wells in the same region and extrapolating the rates for this proposed pad. 

# • The potential emissions are stated in the Application for New Construction (Form NEW), Table E(i) Proposed New Facility. The emissions from the facility fall into the following categories (Le., emitting units). 1. Production Storage Tanks (Oil and Water); 2. Casing Head Gas (Produced Gas); 3. ReCiprocating Internal Combustion Engines (Recycle Pump Engine and Diesel Gensets) 4. Natural Gas External Combustion Units (Heater Treater Line-Heaters); 5. Truck Loading 6. Miscellaneous Fugitive Emissions (Fugitives); 

## 3.1 Production Storage TankVOC Emissions To estimate the uncontrolled PTE of the production tank's vapors (working. breathing, standing, and flashing). extended BTEX low pressure oil analyses were taken from representative wells producing out of the same geological region. E&P Tanks V2 was used to calculate the production tank's vapors using the anticipated maximum production rates, area-specific ambient pressure/temperature data, representative process operating conditions, and sampled analytical data. The E&P Tanks output summary includes all of the needed input data in the emission inventory. such as the vapor rate that is produced from the tanks (scf/bbl), the mol% ofthe vapor components, such as VOCs, HAPs, GHGs, etc. 

# • All applicable uncontrolled emissions from the storage tanks calculations, low pressure analytical data, and E&P TANKS program inputs and outputs are provided in the attachments. 

## 3.2 Produced Casing Head Gas Emissions At the two-phase separator, +90% of all of the initial casing head gas is separated and sent to the gas sales pipeline. After the initial separation occurs, the leftover emulsified oil/gas/water is transferred to the three-phase heater treater. The heater treater then separates the residual gas from the oil and water. Due to the reduced pressure of the heater treater, the sales pipeline pressure is too high to overcome; therefore, the residual gas is routed to the onsite utility flare. Furthermore, if the gas sales pipeline Patricia Charging 2-15H Pad 12/29/11 pg. 7 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •
pressure increases to the point at which the produced casing head gas from the twophased separator cannot be sold or the gas pipeline has a malfunction, the flare serves as an emergency backup. 

## 3.3 Reciprocating Internal Combustion or Compression Ignition Engines Diesel engines connected to generators provide the facility with electricity. The potential emissions from the engines are estimated by assuming the engine is operating 8,760 hours per year and applying the federally required 40 CFR 63 Subpart 

### JJJJ or 40 CFR 60 Subparts 1111 and ZZZZ emission limits as applicable. 

## 3.4 Natural Gas ExternalCombustion Unit Emissions The natural gas external combustion units at the facility are the heater treater lineheaters. Each heater is rated to a maximum capacity of 750,000 Btu/hr. The emissions are based on AP-42 factors and assume the heater is running 8,760 hours per year. 

## 3.5 TruckLoading Emissions The facility is hooked to the oil pipeline via the LACT unit; therefore, no emissions are associated with truck loading. The only time truck loading would occur is under emergency or malfunction situations. 

## 3.6 FugitiveEmissions: Dust and EquipmentLeaks Fugitive emissions from equipment leaks and dust are not required to be estimated for purposes of potential to emit within the NSR permitting program. However, the fugitive emissions will be estimated after a final permit is issued and production begins in order to track to the twelve-month rolling average actual emissions. The fugitive leak emissions primarily consist of leaks from connectors, open-ended lines, valves, pumps, etc. These emissions will be estimated using EPA's average emissions factors for total hydrocarbon emissions from O&G production operations. The fugitive dust emissions will be estimated using AP-42 factors to capture the emissions associated with vehicle traffic at the location. 

# •

•



# • Patricia Charging 2-15H Pad 12/29/11 pg.8 NSR Synthetic Minor Permit Application Project #: WEP211324

# •
4.0 EMISSIONS AND OPERATIONALLIMITS REQUESTS Oatoka-3 is requesting emissions and operational limits at the Patricia Charging 2-15H Pad in order to obtain a synthetic minor status with regard to the NSR permitting programs. The federally enforceable permit conditions will allow Oakota-3 to operate the facility while emitting less than the PSOrritle V major source thresholds of

### 250/100 tons per year of a regulated criteria pollutant, 10 tons per year of an individual HAP, and 25 tons per year of all emitted HAPs. 

## 4.1 Production Storage TankEmissions 

# • The majority of emissions associated with the facility occur from the working, breathing. standing, and flashing vapors from the production storage tanks. Therefore, Oakota-3 will control the storage tank VOC emissions by installing an enclosed smokeless combustion device that has been independently tested and certified to exceed the requirements of 40 CFR 60.18 at 98% destruction efficiency (ORE). Although this control device is certified to meet 99% ORE, Oakota-3 will assume the minimum required 98% ORE for purposes of calculating the controlled tank vapor emissions. This control device will allow Oakota-3 to apply a 98% control efficiency to the uncontrolled PTE. On this basis, the requested emission limit from the storage tanks is: 6.27 tons per year ofVOCs. 

## 4.2 Reciprocating Internal Combustion orCompression IgnitionEngines Oakota-3 will be required to limit the emissions from any reciprocating internal combustion or compression ignition engine being operated at the facility due to the federally enforceable requirements of 40 CFR 63 Subpart 

### JJJJ or 40 CFR 60 Subparts 1111 and 

### ZU2, as applicable. 

# •

Patricia Charging 2·15H pg. NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •
5.0 ALLOWABLE EMISSIONS The allowable emissions are the new estimated controlled potential to emit based on the federally enforceable controls and limits requested in Section 

### 4. The allowable emissions are also presented in the Application for New Construction (Form NEW), Table E(i) Proposed New Facility. 

## 5.1 Storage TankEmissions The storage tank controlled emissions are estimated by applying 98% control efficiency to the uncontrolled VOC, HAP, and CH4 emissions. Although the VOC, HAP, and CH4 emissions are reduced by the smokeless combustion device, CO, NOx • 

### PM, PM10. PM2.5 

# • and N20 emissions are created by the combustion process. These emissions estimates are calculated using AP-42 factors and applying the weight percentages of the criteria pollutant and greenhouse gas components from a representative gas analysis. 

## 5.2 Produced Casing Head Gas Emissions As stated in Section 3, 

### the produced casing head gas is transferred to the gas sales pipeline. However, the residual gas released from the oil/gas/water emulsion in the heater treater will be sent to the onsite utility flare. Furthermore, ifthe gas sales pipeline pressure increases to the point at which the produced casing head gas from the twophased separator cannot be sold or the gas pipeline has a malfunction, the flare serves as an emergency backup. No limits have been requested for the produced casing head gas emissions at the facility; therefore, the emissions estimate is equal to the potential to emit. 

## 5.3 RICE Engine Emissions No limits have been requested for the RICE at the facility. Dakota-3 is required to meet the federally enforceable emission standards depending on the size (hp) and date of manufacture; therefore, the emissions estimate is equal to the uncontrolled potential to emit. 

# • 5.4 Natural Gas External Combustion Unit Emissions No limits have been requested for the natural gas external combustion units 

### (0.5-0.75 MMBtu/hr heater treater line-heaters) at the facility; therefore, the emissions estimate is equal to the uncontrolled potential to emit.

Patricia Charging 2-15H Pad 12129111 pg.10 NSR Synthetic Minor Permit Application Project #: WEP211324 

# •

# •

•

• 5.5 TruckLoading Emissions The facility is connected to the oil pipeline via the LACT unit; therefore, no emissions are associated with truck loading. The only time truck loading would occur is under emergency or malfunction situations if the oil pipeline went down; therefore, no limits are requested. 

## 5.6 Fugitive Emissions: Dust and Equipment Leaks Fugitive emissions from eqUipment leaks and dust are not required to be estimated for purposes of potential to emit within the NSR permitting program. However, the fugitive emissions will be estimated after a final permit is issued in order to track the twelvemonth rolling average actual emissions. The fugitive leak emissions primarily consist of leaks from connectors, open-ended lines, valves, pumps, etc. These emissions will be estimated using EPA's average emissions factors for total hydrocarbon emissions from O&G production operations. The fugitive dust emissions will be estimated using AP-42 factors to capture the emissions associated with vehicle traffic on the location. 

## 5.7 Diesel StorageTankEmissions There will be an onsite storage tank at this facility to store diesel fuel that will be utilized in the diesel gensets. This tank will be either a horizontal or vertical 1,000 gallon tank. Emissions for this tank were estimated using EPA TANKS 4.09d and determined to be less than 0.01 tpy. Because of the low level of emissions from this equipment, it has been determined to have insignificant emissions. The EPA TANKS 4.09d emissions summary output is in Attachment 

### J. 

# I 

# I I I I I

Patricia Charging 2·15H pg. NSR Synthetic Minor Pennit Application Project#: WEP211324


# ..

# • 6.0 PROPOSED MONITORINGAND RECORDKEEPING As per the Application for Synthetic Minor Limit Request (Form SYNMIN), Page 1 

### (8), ATTACHMENTS, Item, 2. Datoka-3 is required to propose testing, monitoring. recordkeeping, and reporting requirements that will be used to demonstrate and assure compliance with the proposed allowable emissions. 

## 6.1 Production Storage Tanks The production storage tanks will have their flashing and standing/working/breathing vapors routed by a closed-vent system to equipment designed to capture the VOC and total HAP emissions generated at the facility for sale or other beneficial purposes, or an emissions control device that achieves a minimum of 98% destruction efficiency. 

# • Dakota-3 will follow the tank manufacturer's recommended maintenance schedule and procedures to ensure optimum performance. Furthermore, Dakota-3 will employ the following methods to ensure the tank vapors are efficiently being routed to the requested proposed device(s): a. Thief hatch covers will be weighted and properly seated; b. Pressure relief valves (PRV) will be set to release at a pressure that will ensure flashing, and standing/working/breathing losses are routed through a closed-vent system to equipment designed to capture the VOC and total HAP vapors. The vapors will be routed to equipment designed for sale or other beneficial purpose, or an emissions control device; and c. Periodic measurements of the peak pressure and vacuum values in the vapor recovery and control systems will be conducted to ensure that the pressure and vacuum relief set-points are not being exceeded (e.g., due to fouling or increased activity levels) resulting in venting and possible damage to equipment. 

### Monitoring Requirements: Dakota-3 will estimate the emissions from the production storage tanks by performing one ofthe following methods: a. Direct measurement of standing/working/breathing losses by sampling and lab 

# • analysis; b. EPA TANKS 4.0.9d to calculate standing/working/breathing losses; c. Direct measurement offlashing emissions by sampling and lab analysis; d. Process simulator such as PROMAX, HYSIM, HSYS using site-specific sampling and lab analysis to calculate flashing emissions in conjunction with EPA TANKS 4.0.9d to calculate standing/working/breathing losses; e. API E&P TANKS Software V2.0 using representative sampling and lab analysis to calculate standinglworking/breathing losses and flashing emissions; or f. Other methods approved by EPA. Patricia Charging 2-15H Pad 12/29/11 pg.12 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • Recordkeeping Requirements: In order to demonstrate compliance with the 12-month rolling emission limits for the oil production tanks, Dakota-3 will track facility oil production rates for each month, beginning with the first full calendar month after operations commenced. The monthly totals will be summed to create a production rate for the prior twelve month rolling operating period. As demonstrated in Attachment 

## e of this application, the total 

## voe, total HAP, and any single HAP emissions in tons per year are directly proportional to the production rate of oil at the facility. Based upon this relationship, compliance with the requested limits in this application will have been maintained if the production rate during any twelve month rolling period is less than the production rate used to establish the emission limits. 

# • Dakota-3 will keep records of all input parameters and calculations, including the input and output reports for the models, used to determine the monthly emissions. 

## 6.2 Production Storage TankEmissions ControlDevice The limits requested on the emissions from the storage tanks are directly dependent on the production throughput in the tanks. All emissions at the facility will 

### be controlled in one or more enclosed combustors and/or utility flares that are designed and operated to reduce the mass content of

## voe (or 

## voe and HAP) emissions in the vapors vented to the device by at least 98%. Dakota-3 will follow, for each enclosed combustion device and utility flare, the manufacturer's written operating instructions, procedures and maintenance schedule to ensure good air pollution control practices for minimizing emissions. All vent lines, connections, fittings, valves, relief valves, or any other appurtenance employed to contain and collect vapors and transport them to the enclosed combustor, or utility flare will be maintained and operated during any time the facility is operating. Each enclosed combustion device will be: 

# • a. Designed to have sufficient capacity to achieve at least a 98% destruction efficiency for hydrocarbon volumetric flow and BTU content routed to the device; b. Operated with a liquid knock-out system to condense any condensable vapors; c. Equipped with a thermocouple to detect the presence of a pilot flame with a minimum accuracy of ±2 percent of the temperature being monitored expressed in 

## °e, or ±2.S 

## °e; d. Equipped with a recording device, such as a chart recorder or similar device, to document the presence of a flame; e. Equipped with an electronically controlled ignition system with a malfunction alarm and remote notification system ifthe pilot flame fails; f. Maintained in a leak-free condition; and g. Operated in a smokeless mode. Patricia Charging 2-15H Pad 12/29/11 pg. 13 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • Monitoring Requirements: Dakota-3 will identify, via an independent engineering analysis or a manufacturer or vendor guarantee, each control device's operating parameters within which they will meet the 98.0% reduction requirement. Dakota-3 will monitor the control device operations to confirm proper operation as follows: a. Monitor the pilot flame using a thermocouple and a chart recorder that indicates the continuous ignition of the pilot flame; b. An inspection of the chart recorder to ensure proper operation will be done whenever an operator is on site; at a minimum, quarterly; c. A visual inspection of the pilot flame to ensure proper operation will be done whenever an operator is on site; at a minimum, quarterly; 

# • d. Measure one other parameter determined during the independent engineering analysis or provide a manufacturer or vendor guarantee; and e. Visually confirm that no smoke is present during operation of any enclosed combustor or utility flare whenever an operator is on site; at a minimum, quarterly. Recordkeeping Requirements: a. Records will be kept of the**site~specific** 

### design input parameters provided for the independent engineering analysis or provided to the manufacturer or vendor and used to properly size the enclosed combustors and utility flares to assure the 98% reduction requirements. b. Records will be kept of all required monitoring ofthe control device operations. c. Records will be kept of any instances in which any control device was bypassed or down in each calendar month, the reason for each incident. its duration, and the corrective actions taken or the preventative measures adopted to avoid such bypasses or downtimes. d. Records will be kept of the any exceedance of the operating parameters specified in the manufacturer or vendor guarantee or engineering analysis and selected for the required monitoring. The records will include the enclosed combustor's total operating time during the calendar month in which the exceedance occurred, the date, time and length of time that the parameters were 

# • exceeded, and the corrective actions taken or the preventative measures adopted to operate the facility within that operating parameter. e. Records will be kept of any instances in which the pilot flame is not present in the enclosed combustor or the utility flare, the date and times that the pilot was not present and the corrective actions taken orthe preventative measures adopted to increase the operating time of the pilot flame. f. Records will be kept of any instances in which the thermocouple (or other heat sensing monitoring device) installed to detect the presence of a flame in the enclosed combustor or utility flare is not operational, the time period during which it was not operational, and the corrective measures taken. 

# • Patricia Charging 2-15H Pad 12/29/11 pg.14 NSR Synthetic Minor Permit Application Project #: WEP211324

# • g. Records will be kept of any time periods in which visible emissions are observed emanating from an enclosed combustor or utility flare. h. Records will be kept of all required testing and monitoring. The records will include the following: 

### i. Date, place, and time of observations, sampling or measurements; ii. Date(s) analyses were performed; iii. Companies or entities that performed observations and the analyses; iv. Analytical techniques or methods used; v. Results of such analyses or measurements; and vi. Operating conditions as existing at the time of sampling or measurement. 

### i. Monitor the pilot flame using a thermocouple, and/or a chart recorder or other means that indicates the continuous ignition ofthe pilot flame; j. 

### A check of the chart recorder or other monitoring device to ensure proper operation will be done whenever an operator is on site; at a minimum, quarterly; k. A check of the pilot flame to ensure proper operation will be done whenever an operator is on site; at a minimum, quarterly; I. Measure one other parameter determined during the independent engineering analysis or provide a manufacturer or vendor guarantee; and m. Visually confirm that no smoke is present during operation of any enclosed combustor or utility flare whenever an operator is on site; at a minimum, quarterly. Dakota M

### 3 will follow, for each enclosed combustion device and utility flare, the manufacturer's written operating instructions, procedures and maintenance schedule to ensure good air pollution control practices for minimizing emissions. 

## 6.3 Produced Casing Head Gas Emergency Utility Flare Dakota-3 is not requesting any limits from the produced casing head gas because it is being sent to the gas sales pipeline. If a malfunction from the pipeline occurs and the gas cannot be sold, Dakota-3 will record the volume of gas sent to the emergency utility flare
. During an emergency or malfunction Dakota-3 will route the produced casing head gas to the onsite utility flare that will be designed and operated to reduce the mass content of VOC (or VOC and HAP) emissions in the vapors vented to the device by at least 98%. Dakota-3 will follow, for the utility 'flare, the manufacturer's written operating instructions, procedures and maintenance schedule to ensure good air pollution control practices for minimizing emissions. All vent lines, connections, fittings, valves, relief valves, or any other appurtenance employed to contain and collect vapors and transport them to the utility flare will be maintained and operated during any time the facility is operating. Patricia Charging 2-15H Pad 12/29111 pg. 15 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •
The emergency utility flare will be: a. Designed and operated in accordance with the requirements of 40 CFR 60.18 and 40 CFR 63.11. b. Designed to have sufficient capacity to achieve at least a 98% destruction efficiency for hydrocarbon volumetric flow and BTU content routed to the device; c. Operated with a liquid knock-out system to condense any condensable vapors; d. Equipped with a thermocouple to detect the presence of a pilot flame with a minimum accuracy of ±2 

### percent of the temperature being monitored expressed in °C, 

### or ±2.5 °C; 

### e. Equipped with a recording device, such as a chart recorder or similar device, to document the presence of a flame; f. Equipped with an electronically controlled ignition system with a malfunction alarm and remote notification system ifthe pilot flame fails; 

# • g. Maintained in a leak-free condition; and h. Operated in a smokeless mode. 

### Monitoring Requirements: The monitoring requirements for the emergency utility flare will be the same as described above for the production storage tanks control device as specified in Section 

### 6.2. Recordkeeping Requirements: The recordkeeping requirements for the emergency utility flare will be the same as described above for the production storage tanks control device as specified in Section 

### 6.2. 

## 6.4 RICE Engines Depending on the size (hp) and date of manufacture, Dakota-3 is required to meet the emission standards set forth in 40 CFR 63 Subpart 

### JJJJ or 40 CFR 60 Subparts 

### 1111 and ZZZZ, as applicable. Dakota-3 will properly operate and maintain the engines as per the manufacturer's specifications to ensure compliance with the above standards. If the 

# • engines emissions are not certified to meet the required standards, Dakota-3 will have performance tests conducted on the engines as required by the applicable subparts. 

## 6.5 Natural Gas-Fired External Combustion Units Due to the insignificant emissions associated with the 0.5 to 0.75 MMBtu/hr natural gas (or propane) fired line-heaters, no monitoring or recordkeeping requirements are being proposed by Dakota-3.

Patricia Charging 2-15H Pad 12/29/11 pg.16 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

## 6.6 TruckLoading The truck loading rack is designed for submerged filling of the tank trucks. This is standard operating procedure. Monitoring Requirements: The monitoring requirements for truck loading will be estimating the monthly VOC, total HAP, and any single HAP emissions from the loadout operations using input parameters, equations, and emission factors from AP-42, Fifth Edition, Volume I, Chapter 5.
, 

### I

# • Recordkeeping Requirements: Total VOC, total HAP, and any single HAP emissions, in tons, from loading operations will be calculated and recorded at the end of each month, beginning with the first full calendar month after operations commenced. Prior to twelve full months of operation, Dakota-3 will, at the end of each month, add the emissions for that month to the calculated emissions for all previous months since operations commenced, where applicable, and record the total. Thereafter, Dakota-3 will, at the end of each month, add the emissions for that month to the calculated emissions for the preceding eleven months and record a new twelve-month total. Dakota-3 will keep all input parameters and calculations used to determine the monthly emissions. 

## 6.7 Fugitive Emissions: EquipmentLeaks Dakota-3 will minimize leaks of volatile organics from each piece of equipment in hydrocarbon service at this facility. Work Practice and Operational Requirements: 

# • a. At a minimum, Dakota-3 will detect and repair leaks at each tank thief hatch, centrifugal compressor vent, reCiprocating compressor vent, instrument, meter, diaphragm, pressure relief device, dump arm, open-ended valve or line, vent line, flange, connection, fitting, or any other appurtenance employed to contain and collect vapors and transport them. b. Dakota-3 will make the first attempt to repair any leaking equipment within five days after the leak is detected. c. Any leaking equipment will be repaired as soon as practicable, but no later than 15 days after the leak is initially detected, unless the repair is technically infeasible without a facility shutdown. Such equipment will be repaired before the end of the first facility shutdown, after the leak is initially detected. Dakota-3 will make the first attempt to repair any leaking equipment within five days after the Patricia Charging 2-15H Pad 12/29/11 pg. NSR Synthetic Minor Permit Application Project #: WEP211324 

# •

# •
leak is detected. Oakota-3 will minimize leaks of volatile organics from each piece of equipment in hydrocarbon service at this facility. Monitoring Requirements: 

### a. Oakota-3 will conduct leak detection monitoring on a semi-annual basis. If no instrument reading of 10,000 ppm or greater is measured for 

## two consecutive semi-annual monitoring periods, the required monitoring frequency will change from semi-annual to annual. If any single instrument reading of 10,000 ppm or greater is measured, the required monitoring frequency will change back to semi­ annual. b. Oakota-3 will use one of the following methods to conduct leak detection of the equipment: 

### i. Method 21 

# • a} Use the equipment leak detection methods in 40 CFR Part 60, Appendix A-7, Method 21; and b} If an instrument reading of 10,000 ppm or greater is measured, a leak is detected. ii. Optical Gas Imaging Instrument a) Use an optical gas imaging instrument for equipment leak detection in accordance with 40 CFR Part 60, Subpart A, §60.18(i)(1) and (2) ofthe Alternative workpractice formonitoring equipmentleaks; 

### b} Any emissions detected by the optical gas imaging instrument are a leak unless screened with Method 21 (40 CFR Part 60, Appendix A-7) monitoring, in which case 10,000 ppm or greater is designated a leak; c} The optical gas image will include an image of the equipment in addition to any observed leaks; and d} The optical gas imaging instrument will be operated in accordance with the instrument manufacturer's operating parameters. iii. Operator Developed Inspection Protocol - Best Management Practices a} Develop and use a written inspection protocol approved by EPA, based on best management practices, for leak detection; b) Any emissions detected by the protocol are a leak unless screened with Method 21 (40 CFR Part 60, Appendix A-7) monitoring, in which case 10,000 ppm or greater is designated a leak; c) The protocol will include the following: 

# • I. A detailed description of the best management practice to be used for leak detection; II. A requirement to use a log book that contains a list, summary description, or diagram showing the location of all equipment in hydrocarbon service at the facility, and the required recordkeeping for equipment leaks; and III. A requirement that the log book be Signed by the inspector at the completion of each inspection. Recordkeeping Requirements: Patricia Charging 2-15H Pad 12/29/11 pg.18 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •

a. Dakota-3 will document and maintain a record of each leak detection inspection and repairs. b. All leak detection inspection records will include, at a minimum, the following information: i. Date ofthe inspection; ii. All documentation and/or images produced in the inspection; iii. Findings ofthe inspection; iv. Any corrective action taken; and v. Inspector's name and signature. 

## 6.8 General Recordkeeping Requirements 

# • Total 

## vec{or

## vec, total HAP, and any single HAP) emissions, in tons, from each piece of equipment will be calculated and recorded at the end of each month, beginning with the first full calendar month after operations commenced. Prior to twelve full months of operation, Dakota-3 will, at the end of each month, add the emissions for that month to the calculated emissions for all previous months since operations commenced, where applicable, and record the total. Thereafter, Dakota-3 will, at the end of each month, add the emissions for that month to the calculated emissions for the preceding eleven months and record a newtwelve-month total. Dakota-3, when feasible. may use a Supervisory Control and Data Acquisition (SCADA) system to monitor and record the needed data. SCADA consists of computer systems that monitor and control industrial. infrastructure. or facility-based processes. The system may include, but is not limited to. production monitoring, electronic pressure indicating transmitters. pilot flame status monitoring, valve position setpoints, temperature monitoring. alarm notification. data logging, flowmeter monitoring, etc. 

# •

Patricia Charging 2-15H Pad 12/29/11 pg.19 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 7.0 QUALITATIVE AIR QUALITYASSESSMENT The climatology and air quality of the area of interest is dominated by continental air masses with only minor terrain features (from a synoptic point of view) of interest. The area has excellent ventilation since large air mass movement is not limited by any significant geologic features. This is in stark contrast to other areas in Region 8 that may have limited atmospheric mixing due to mountain valleys or large mountain ranges that can minimize the effect of air mass movement. Ambient air quality data has been gathered in and near the reservation for many years. The results of that ambient monitoring network indicate ambient concentrations of all pollutants well below the National Ambient Air Quality Standards (40 CFR 50). Those measured values include the impact of substantial oil and gas development that has occurred in the region including development near the proposed facility. In fact, much of the monitoring data yields background values despite the presence of current industrial activity and general anthropogenic sources. The reported data shows that the values are the same or nearly the same as one would find in a rural location devoid of any industrial activity (although industrial activity is clearly nearby). A typical facility's actual emissions are modest in nature (i.e., below typical permitting thresholds) as demonstrated in Figure 2; therefore. additional ambient impact analysis is not warranted. 

# •

•

Patricia Charging 2·15H Pad 12129/11 pg.20 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 8.0 ENDANGERED SPECIESACT The Endangered Species Act (ESA) requires EPA, in consultation with the U.S. Fish and Wildlife Service (USFWS) and/or the NOAA Fisheries Service, to ensure that actions EPA authorizes are not likely to jeopardize the continued existence of any listed threatened or endangered species (TES) or result in the destruction or adverse modification of designated critical habitat of such species. TES are considered to be those species recognized by the USFWS as listed or proposed species, and those designated as candidate TES under the ESA. Whether critical habitat for TES exists near the facility will first be assessed by consulting the USFWS North Dakota Ecological Service Field Office website (http://www.fws.gov/northdakotafieldoffice/index.htm) and noting the potential occurrence of each TES by county. Once the potential presence of a species is assessed, a look at whether any critical habitat exists in the vicinity of the facility will help determine the possibility of any impacts from the facility on TES. EPA will conduct an evaluation of the potential for TES impacts from the facility and consult, as appropriate. with USFWS regarding identification and mitigation of any impacts. 

# •

•

Patricia Charging 2·15H Pad 12/29/11 pg.21 NSR Synthetic Minor Pennit Application Project#: WEP211324 

# •

# • 9.0 NATIONAL HISTORIC PRESERVATIONACT The National Historic Preservation Act requires EPA, in consultation with State and/or Tribal Historic Preservation Officers, to ensure that actions authorized are not likely to affect cultural resources. The potential for cultural resources in the vicinity of the facility will be assessed by consulting with the North Dakota State Historic Preservation Office (NDSHPO) and the Tribal Historic Preservation Officer(s), and conducting a literature review of available information from the area immediately surrounding the facility (http://history.nd.gov/hp/siclass1.html). If the review finds a need for more intensive analysis ofthe immediate area ofthe facility. a Class II or III cultural resources inventory may be performed as required. EPA will conduct the consultation with NDSHPO and Tribal officials to identify any cultural resources that could be impacted by the facility and any needed mitigation measures for those impacts. 

# •

•

Patricia Charging 2-15H Pad 12129/11 pg.22 NSR Synthetic Minor Pennit Application Project#: WEP211324 

# •

# • ATTACHMENT B: EMISSION INVENTORY



# •

•

Dakota-3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324 

# •

# • • 

# •

Fac!IIty_lnformation Patricia Charging 2-15H Pad ,a.ssociated Wells: Patricia Charging 2-1SHC. 2-15HO Not Producing Yet !U8IJI BOPO 965 ,DracIucIIon III
...... of01
....... on'"pNdIcIodlint3G dovI dIproductlo.. Mscfd 671**~...,...**ddv prod_", _IIIMoc:I....dIr. bMod on'" pnldlclld lint3GdovI dIproduction. 

# •

GREEN. Requires Input RED = No input required. This is a calculated value. 

# b·
.._ ......·_· I ;. .. IInt
.....",prod_or
........ ",lIIOdIIIcIIIoIIdI
... ...,. 

### Input Data 

# Dal<ota-3 

# EIP**Com~an~,** 

# [LC

Decline Factor 0.530 dod
..........""
... 1Int,...-ofopondloll. on .....1rom pnMoUllyproduclng
..... III
... .- fIoIdand Iorrnollon. i'djusted BOPO 512 1Th
....... clio
.... BOPO -"'lID III prod"'"wing ....... _ ....docIIN....... :Adjusted Produced Gall (Mscfd) 356 irhII_........... mcfllofSJM_
.........**--..ID~** wing'".............dod
........... OlllCondeneateTank Date Description 

## '*......... down IIIIIIU IDchooM
...__W g_moIhod. Flash Gas Method: Prooess Simulator Process Simulator Estimated IICflbbl 40.23 

## 1'''...**fjbbllrom''-_lIIIIIIIIor~** ...1o.**~on ~EII'TonkEmIoo'"**  su""",oyOuq,Ul Estfmeted Tank Vapolll (acfd) 20687.28 1Ib
....... 1IIlIMIodtcId ofllllk_"bModon
... foIowIng: ........BOPO Iftu
.......by'"tcMIbl
.........on Unt.. Lower Heatlna Value 2401.97 '-'>-hoIIfng
..... (hftoIIdlllnk_".S-on

__ EII'T.nkEmioolonllum
...ryOuq,Ul MolecularWeight 42.14 [MoIoculorwolglttof
... llllk_1n poundo pofpolllllkdl**~II~** lIMNon

__ Ell'Tift.EmIl....Summory 0tJIput. VOC% 74.026 

### rvoc wooIgIttfrocllon "'
... IIIIk_r_(C3+).**~.n** ""'_ESP Tonk Emiooion SummoryOuq,Ul VOC TPV/BOPD Emission Factor 0.613 lIMN
.. Ell'Tonke_1lum1lllllYOuq,ut. {Su"""""OUCpIll,,_. 1_
......noblp b_TPYand BOPIll HAP% 1.046 '"' woIgIttfrocllon dI
... llllk_r_. on

__ Ell'Tlflkem
......SUlftmooy 0tJIput. HAP TPYIBOPD Emission Factor 0.009 on 11""",,,-_Ell'Tank£mIooloo SumllllllYOUCpUl (Su"""""OUCplllc_.

__NlItIonahip _ TPY In<! BOPO) C02% 0.26% !CO2woIgIttfrocllon "'
... lInk

___• lIMNon

__ ElP T.nk EmIooloo S
....mooy Ouq,ut. H4wo1g1ttfrocllondl
... llllk

___.IIMN••

__ EIPT
...kE
.....ionS
....mooyOuqoUl CH4% 1.99% H2S_lght% 0.09% WIIgIIt,.,.,..mdl"'lInk_r.... IIMN""

__ Ell'T
...kEmIl....s.... mooy Output. moll,.,.,..m"'
... lInk
__ .... lIMNon """

__ Ell'T.nkEmIooIo. Surnmory Ouq,ut.**~Smole%** 0.10% 

## '*... chpdownllllllUlDc'-
... ___ion......nl""'" Enclosed Smokeless CombuslDr Control Destruction Efficiency 98% !ControloIIIcloncyof..,.
............oonImIo. ThllII.ftIOId
......... bModon......nl ""'"

# • 

# • Oakota-3 E&P Company, llC Input Data GREEN =Requires input FacllltylnformatJon RED • No Input required. This IIa calculated value. Patricia Charging 2·15H Pad Associated Well
..: Patricia Charging 2.15HC. 2·15HO

# Loflht~ ... Iht
...

## O"""" Treater Gal Date Descrlotlon I Btu/set 1700.39 lltullCfo,..............(Ftom "",_tIoIdpilltOlyoltl I MolecularWeight 29.65 ...... mo

__**woIghIoflht"""""pllII~.(F_** ..p_fIoldpl ...IyoIl, I Specific Gravity 1.02 II-..y" _rllIf*I"camt!¥10..............Ight,_.IhtIIf*I"cg'"""oflht.......... pl.tF"'M

__tIoIdpilltOlyolt) Average MolecularWeight 29.65 

### "'_..,,-fIoId._onoIyoool VOC% 45.94% vae woIghIfnIcIIon ofIht
..........pitNoIa:Wtlglrt%. nDI**M%'Ao~** (From

__fIold ._IItOIyoIt) HAP% 1.28%**~p** woIghIfnIcIIon oflht.............. tNoIa:WIIighf.%. nDI M%'Ao). (F...m ""'_tIoIdpllnoIyoll) C02% 0.863% C02wo1gh1fn1c11on**o!lht~pI.** (NoIII:WIIighf.%.**nDlM%'Ao~** (F- "",_fIolI! pllItOIyoll) CH4% 25.747% CH4woIghtrr.:tIonofIhtwtIIIIrulll
.... tNoIa:w.1gIft. nDI**MoII%~** (Fn>m "",NI_tIoIdpllItOIyolt) H:.S weight % H:.S mole % O.OOO"k 0.000%**IItSwoIghtpooanto!lht~** .... IF"'M"",,_,_fIoIdpilltOlyolll 1ItS ....**...-.toflht~** .... tFn>M"",_fIoldpilltOlyoltl Connected to ..les line UNlhtdropdown.........<'-Iht"""""'

__......**nfIIlI~** Contro/lCapture Ellk:lency 100% rouItNI*, plpol... --.11_0IpIUn ofpl.'1Ionod,_11IIIIcIIMo:y01...,oppIIcIb"00fttnIIelcomb-.plllo
.., uIIIIIy1Io...**11I:~** Treater Bumer(l) DeacrtDtlon Talal Btulhr 1500000 lI'olIIbu_IlIIIna",lhthullrtrMlorburMrfl,lnll4ulhr••Iht
.......... bu...... lddlht_hutlnput....-. Hours ofOperation 8,760 !Thob""""'.j.... --.I
..__ 1,710hotIrt ....._. Truck loading DeacrlDf;lon Oil IIsold Ihrouah LACT UNIhtdrolldown .......*,<'-tIIt_ ......011 ... IMIhod. I •• "1OId 1MIugh.LACT no Input"... .. _1Nd10u...JO.U. Submerged loading: dedicated normal service 0.6 UNIht......downIIotlochooulht_ ......**modoof~** Tho -.aottfllDrwll btMIoo1IodbINdon modo '"ope_. MoIocuIotwolghlofllllltwpo..ln
...........__ ............woIght_ fIolhlng

__ '"'"'''''''''- ElPTlnko_ MolecularWeight 42.14 Vapor Pressure 2.30 "'buIk.....Id,......InFahnnhllt.rno....pecIIc_ .........._ ...........**_-....~** Temperature SO.OO Load Rate (bbllhr) 180 

## '"'*.... ofliquidIHdod In btrNII
.....hour. Load Time (hrs) 1.00 !Tho
.... ItIl... 1D 1NdoIII_1oId**(h",~**


# • IPriiiiimatICPumpe and CoIitOlJera(None) IGIycOI Dehydrator (None)


# • ..... ","- InchobtoluloIPoW.no ..........._ ......................." 1ob1o20. Truckl.oldlnglib.

# • • 

# n Dakota-3 E&P

# Com~anYI LLC

# II •

FaclHtY: Patricia ChIlrglng 2·15H Pad IAssociatedWei,.: IPatriCIa Charging 2.15HC. 2­ 1'5HD

OillCondensate Tanks CasillQ Head Gas Treater Surner RICE Engine Truck loadillQ Fuel StoraaeTank Pneumatic PumD Pneumatic Controllers GlYCOl DehYdrator ITotals !'!P:!l

OillCondensate Tanks casing Head Gas Treater Burner RICE EIlQine Truck loadillg Fuel Sioraae Tank Pneumatic PumD Pneumatic Controllers Glvcol Dehydrator ITotals (TPY) VOC 313.49 4.67 0.04 2.27 NIA Nl!gIigibie

NIA NIA N/A 320.46

voc 6.27 4.67 0.04 2.27 N/A Nealiaible

N/A N/A NlA 13.24 

### Uncontrolled Potential to Emit Criteria Pollutants HAP NOx PM PM10 PM2.$ 4.37 NIA NIA N/A N/A 0.13 0.75 0.05 0.05 0.05 0.01 0.64 0.05 0.05 0.05 3.40E-02 8.70 0.05 0.05 0.05

NlA NlA NIA N/A N/A Negligible N/A N/A NIA N/A

NlA N/A N/A NIA N/A N/A NIA N/A NfA NlA N/A N/A N/A N/A N/A 

## II 4.55 

### I I 10.09 

# I I 0.15 

# I I 0.15 

# I I 0.15

HAP 0.09 0.13 0.01 3.40E-02

NlA Nealiaible

NlA NIA NlA NOx 0.61 0.75 0.64 8.70 N/A N/A N/A NIA N/A 

### Emission Summary

Allowable Potential to Emit

PM 0.03 0.05 0.05 0.05 N/A N/A N/A NIA N/A 0.26 10.71 0.18 

## I I I I 

# I I Criteria Pollutants" PM10 0.03 0.05 0.05 0.05 NlA NlA N/A N/A N/A 0.18 PM2.5 0.03 0.05 0.05 0.05 NfA N/A NIA N/A NlA 0.18 

## I 

# I

I I CO NIA 4.09 0.54 14.36 N/A N/A NIA N/A N/A 18.99

CO 3.34 4.09 0.54 14.36 NIA N/A NIA NlA NIA 22.33 

## I I



## I I H2S N/A NA NIA NIA N/A N/A NIA N/A NIA 0.00**H~** N/A 0.00 N/A N/A NfA N/A N/A N/A NIA 0.00 

## I I



## I I 502 NIA 0.00 0.00 4.14E-02

N/A N/A NIA N/A N/A 0.05

502 N/A 0.00 0.00 4. 14E-02

N/A N/A NIA NlA NIA 0.05 

# •

HCHO Negligible

0.00 Negligible

0.03 Negliaible

N/A Negligible Negligible Nealiaible 

## I I 0.03

HCHO Negliaible

0.00 Nealiaible

0.03 Nealiaible

N/A Nealioible NealiQible Negligible

0.03 Emis.ions of lead and lead compounds, fluorides, sulfuric acid mist, tolal reduced sulfur, and reduced sulfur compounds are assumed \0 be negiigable for upStream oil & gas operations onIhe FBIR.

# • 

# • CH, H 2O Oil/Condensate Tanks 8.31 0.01 Casina Head Gas 2.62 0.00 Treater Bumer 0.04 0.01 RICE Enaine 0.11 0.02 Truck Loadina 0.00 N/A Fuel Storaae Tank N/A N/A Pneumatic Pump N/A NlA Pneumatic Controllers N/A N/A GIvcoI DehYdrator N/A NIA

2087.07 2155.25

No Facility: 

# n Oakota-3 E&P

# Com~any, LLC

# I] I PatriciaCharging 2·15H Pad AHoclated W.".: Pa1r1cla ChIll'lJI"9 2·15HC. 2· 15HD

Potential To Emit Actual Greenhouse Gasesb Greenhouse Gasesb CO2 H 2O CO2 CH, N/A N/A 451.97 0.00 783.65 0.00 783.65 2.62 772.94 0.01 772.94 0.04 7.57E+01 0.02 7.57E+01 0.11

0.00 NIA 0.00 0.00 NIA N/A N/A NlA N/A NIA NIA N/A NIA N/A NlA NIA N/A NfA NIA NlA 'Totals (TPy) 

## I I 1632.29 

## II 11.08 

## II 0.03 

## I I 2084.26 

## I I 2.77 

## I I 0.04 

## I OHG M••• E
......lon. (Ipy): I 1843.41 I GHG Mass Emission. (tpy): C02·11py): I 1875.11 I C02e IIpy): Applicable tothe r.IIOri119 Rule?: 

## -,



# • " H)'drofllJtJtO<:8l1lOOs (HFCs).**p.rn~** (PFCsl, and**Su~u'** He
...ftuorides (SF8) em;..lono "'"no! cnsated from O&G prn<!uctIon_",lions.



# •

# • • • 

# •
[ Dakota-3 E&P Company, LLC 

# I
Patricia Charging 2·15H Pad Associated Wells: Patricia ChargiI'lQ..2·15HC. 2·15HO 

## Tanks

Oil Production! 512 BOPO Flare Gas VoIume[ 20.587 

### --sa7daY] Lower Heating Value! 2401.97 Blulscf Molecular WeightC -42.14
- IDJIl:Hi1Ole) VOC wt FractionC 14]13%­ VOC Emission Factor[-0:613--tpYTbOpd' HAPs: Benzene wt Fraction 0.0285% I Toluene wt Fraction 0.0166% I E-Benzene wt Fraction 0.0033% I Xylene wt Fraction 0.0191% I n-Hexane wt Fraction 0.9045% I 2.2,4-Trimethylpentane
.....

### -.:-p'=-'_" wt Fractionl 0.0739'14 HAP Emission Factor[

### -o:ooa- - iPedl C02wt Fraction[ 0.26% CH4 wt FractionC**-;L~**

Controlled emissiOns are calculaled based on a**~deslruction** efficiencyof the voe gas

# • 

# • r Dakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: Patricia Charaino 2-15HC, 2-15HD 

## Tanks CRITERIA POLLUTANT EMISSIONS8 Uncontrolled VOCs (PTE): Using E&PTanks Run: 

## I 0.613 TPV VOC/BOPD 

## I x 511.74 BOPO x 

## I ORE 0% 313.49 TPvl Controlled VOCs (Allowable): USing E&PTanks Run: 

## I 0.613 TPV VOC/BOPO 

## I x 511.74 BOPO x 

## I ORE 98% 6.27 TPvl Uncontrolled HAPs (PTE): Using E&P Tanks Run: wt% Benzene 858 scflhr 858 scflhr 858 scflhr 858 scflhr 858 scflhr 858 scflhr x 1/379scfllb-mole 1/379 scfllb-mole 1/379 scfllb-mole 1/379 scfllb-mole 1/379 scfIIb-moIe 1/379 scfflb-mole x 42.14 Ibllb-mol 42.14 Ibllb-mol 42.14 Ibllb-mol 42.14 Ibllb-moI 42.14 Ibllb-mol 42.14 Ibllb-mol x**~** E-Benzene x x x**~**

Toluene x x x

### ~ n-Hexane x x x

### ~ Xylene x x x

### ~ 2.2.4-Trimethylpentane x x x**~** ORE TPY 0% 0% 0% 0% 0% 0% 0.031blhr 0.00 Iblhr 0.021b1hr 0.861b1hr 0.021b1hr 0.071b1hr 

# .. 0.12 x 

### = 0.01 x 

### = 

# .. = 0.07 x = 3.78 x = 

# .. = 0.08 x " 

# .. 0.31 x =

Benzene 858 scflhr 858 scflhr 858 scflhr 858 scflhr 858 scflhr 858 sctlhr x 11379 scfllb-mole 11319 scfllb-mole 1/319 scfllb-moIe 11319 scfllb-mole 1/379 scfllb-mole 1/379scfllb-mole


# • Controlled HAPs (Allowable): x 42.14 Ibllb-mol 42.14 Ibllb-mol 42.14 Ibllb-mol 42.14 Ibllb-mol 42.14 Ibllb-mol 42.14 Ibllb-mol x E-Benzene x x x Toluene x x x n-Hexane x x x

Xylene x x x 2.2.4-Trimethylpentane x x x


# • "'ii.ii3%

## ~**~ ~**  0.02%**~** Uncontrolled TOTAL HAPS (TPV) = I 4.37

98% 98% 98% 98% 98% 98% 0.00 x O.OOlblhr O.OOlblhr O.OOlblhr 0.021blhr O.OOlblhr O.OOlblhr 

### = = 

# .. 0.00 x = 0.00 x 

### = " 0.08 x = 

### = 

# .. 0.00 x 

### = 

# .. 0.01 x " 0.09 Controlled TOTAL HAPS (TPV) 

# ..

# • • • 

# •
[ Dakota-3 E&P Company, LLC Patricia Charging 2·15H Pad Associated Wells: Patricia Charging 2·15HC. 2·15HD 

# [**hn~** Uncontrolled NOx: Nox:l 0 scflhr x 

### I 2,402 Btulscf

### I
0.00 Iblhr )(
x 1 MMBful1,OOO.OOO Blu
8760**hr/~** x 

## I x 

### I 0.068 IbIMMBtu 

### I
1 lonI2OOO Ib 0.00
0.00 Iblhr!
TPV

## I NOx Created by Combustion (Actual) NOx:1 858 scflhr x 

### I 2,402 Bfulscf

### 1
0.14 Ibi&] x
x 1 MMBlul1,OOO.OOO Btu
8760**hr/~** x ! x 

## I O.068lb1MMBlu 

## I
1 lonI2OOO Ib 0.14
0.61 lbihr

### 1
TPV 

### I Uncontrolled PM:
PM:l 0 scllhr x 

## I 7.6
0.00 1b/1.000.000sci Iblhr x 8760 hr!l!; 0.00
x lbihr
1 lon/2000 Ib 0.00 TPY PM Created by Combustion (Actual)
PM:! 858 scf/hr x 

### I 7.6
0.01 Ib/1.000,OOO sef Iblhr 

### I x 8760 tlrlyr
_ 0.01 

### 1 )( Iblhr**!1-'on~lb** ]**I~_TPY:J**

# • 

# • I . Dakota-3 E&P Company, LLC Patricia Charging 2-1SH Pad Associated Wells: Patricia ChaI"Qi.rlQ..2-1SHC, 2-15HD

Uncontrolled CO: 

### co:1 0 scflhr 

### I )( 

### I 2,402 

## I 0.00 Btu'Scfl
Iblhr 

## I x
)( 

### I 

## I 1 MMBtu'1.000.000 Btu
8760 hrl:e; 

## I x 

### I 

## I )( 

### I 0.370 IblMMBlu 

### I
1Ion12000 Ib 

## I ::: ::: 

### I 0.00 

## I 0.00 Iblhr

### I
TPY 

## I
CO Created byCombustion (Actual, 

### CO:1 858 scflhr 

### I )( 

## I 2,402 BllO'scfl )( 

## I 1MMBtu'l.000.000 Btu 

## I x 

## I 0.370 IblMMBtu 

## I ::: 

## I 0.76 Iblhr

### I 

## I 0.76 Iblhr 

## I )( 

## I 8760 hr!:e; 

## I )( 

## I 1 tonl2000 Ib 

## I ::: 

## I 3.34 TPY 

## I

.NOx. S02. and CO emission factors are from AP·42 Table 13.5·1 (Emission Factors for Flare Operations)
.



# • I Tanks - 

# I



# •

# • 

# • • 

# •

I Tanks _._. --] 

# Oakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: PatriCia Charaing 2-15HC. 2-15HD


## REGULATED GREENHOUSE GAS EMISSIONSb Uncombusted CO2: C02:1 858 scflhr x 111379 scf/lb-mole 

### I x 0.25 42.14 1Mb-mole

### I
Ib/hr x WI x 10.26% 

### I
8760 hr/t!; x 

## I ORE x 0% 1 1onJ2000 Ib 0.25 1.10 Ib/hr TF'Y C02 Created by Combustion (Actual) c02:1 858 scflhr x ,'20.000.0 Ib/1.000.000 sef**1~2.94 ---.lblh~**  

### I x**L.876~_]** 102.94 Iblhr

x C1 ton/@QjiQ 

### I 450.86 TF'Y

# • • 

# • 

# • Uncontrolled CH4: CH.:I 858 --scfihr 1 x [1/319 scf/lb-mole I x [4L!:rlMtHnOt!l x wt 11.99% 

### I ORE x 0% 1.90 lblhr -­ 

## J
1.90 Iblhr x 8760 hrlyr x 

### I 1ton/2000 Ib ;:: 8.31 TPY 

### ::J Controlled CH4: (Actual) CH4:1 8511­ -scf7hr

## J x 11/379scf/lb-mole 1 x 42.1r Ib7ItHnOle! x wt% 11.99% 

### I ORE x 98% 0.0. Ib/hr 

## J
0.04 Iblhr x 8160 hrlyr x 

### I 1tonl2000 Ib 0.17 TPY ] 

# Dakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: Patricia ChllrgLng2-15HC. 2-15HD 

## Tanks

# • • •

[ Dakota-3 E&P Company, LLC 

# •

Tanks 

# I Patricia Charging 2·15H Pad Associated Wells: Patricia Cha19il'lg 2·15HC. 2-15HD

Uncontrolled N20: CH4:1 858 scflhr x 11/379 scfllb-mole 1 x 0.00 42.14 Ibllb-molel Ib/hr x wt% x 10.00% 

### I
8160 hr1f x 

## I ORE x 0% 1tonl2000 Ib 0.00 0.00 Ib/hr TPY N20 Created by Combustion: CH4:1 858 scf/hr x 

## I 2.3 Ibl1,OOO.OOO sef 0.00 Ib/hr 0.00 Ib/hr x 8760**hrl~** x 1 1011/2000 Ib 0.01 TPV C02 and N20 emission factors are from AP-42 Table 1.4-2 (Emission Factors for Natural Gas Combustion).

# • • • 

# • Oakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: Patricia Chargil1g 2-15HC. 2-15HD

Flare Gas Volume[ 1,483 scflhr !(Takes into account the 10% ofthe total produced gas volume that is not being sold.) Lower Heating Valuer 

### I**-1~7~00~.-=3~86~5=7:'!"1--:B""tu""lf!'"scf""'" -"**  Avg.**Molecular Weight!'-~65---'~**  VOC wi fraction! - 45.94% HAP wi fraction Benzene wifraction E·Benzene wifraction

Toluene wi fraction n-Hexane wi fraction

Xylene wi fraction 1.28% 0.15% 0.01% 0.18% 0.84% 0.10% 

## Casing Head 

## Gas-I

2,2,4-Trimethylpentane..-_-=-::::-_--, wi fractlonl 0.00% C02wi fraction!**~O-:n%-** 

## J CH4 wi fractlonl-**25.75 %~**  

### J Hours of Flaring

### frni 8760 hourslyr PTE:.IL

_________ Control Effllcienc' 98% ORE

# • 

# • • • ,,,..**#J~'~**



# [ Dakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC. 2-15HD



# - - - - - - - - - - -Casing 

# Head

# Gas- - - - - - - -I CRITERIA POLLUTANT EMISSIONSa Controlled VOCs (PTE): 

### voe:1 1.483 scflhr x 111379 scfltb-mole x 1.07 

### 129.64686 Ibllb-mole , x Iblhr x 8760**hrl~** wt% Conlml% 45.94%1 x 1 98% 1

x 11 tonl2OOO Ib 1.07 Iblhr 4.67 TPV Controlled VOCs (Allowable): 

### voe:, 1.483 scflhr x 111379 scfltb·mole x 

### L 1.0] 129.64686 Ibllb-mole 1 x -'b/Il'- 

## _I x**1_8760~_J** wt".4. Conlml% 45.94%1 x 1 98% 1

x 

### h tonl2000

## 1"-_' 1.07 Iblhr _4.67_TPVJ

# Oakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: Patricia Cha!9!rut**~15tiC,** 2-15HD



### Casing Head Gas
Controlled HAPs (PTE): Using E&P Tanks Run: Benzene 1,483 scflhr x E-Benzene 1.483 seflhr x

Toluene 1,483 scflhr x n-Hexane 1,483 scflhr x

Xylene 1.483 sef/hr x 2.2.4·Trlmethytpentane 1,483 scflhr x Formaldehyde 1,483 seflhr
Controlled HAPs (Allowable): Using E&P Tanks Run: Benzene 1,483 scflhr x E-Benzene 1,483 sef/hr x

Toluene 1,483 scflhr x n-Hexane 1,483 seflhr x

Xylene 1,483 sef/hr x 2,2,4·Trimethytpentane 1.483 scflhr x Formaldehyde 1.483 scflhr x


# • • 1/379 scfllb-mole 1/379 scfllb-mole 1/379 scfllb-mole 11379 scfllb-mole 11379 scfllb-mole 11379 sefllb-mole 7.50E-02 IblMMsef 

## I 0.03

1/379 scfltb-mole 11379 scfflb-mole 11379 scf/lb-mole 1/379 scfflb-mole 11379 scfflb-mole 1/379 scf/lb-mole 7.50E-02 IblMMscf 

### I 0.03 x 29.64686 Ibllb-mol x x 29.64686 Ibllb-mol x x 29.64686 Ibllb-mol x x 29.64686 !bllb-mol x x 29.64686 Ibllb-mol x x 29.64686 Ibllb-mol x tblhr 

## I x 

## I 8760 hr!f; 

## I

x 29.64686 Ibllb-mol x x 29.64686 Ibllb-mol x x 29.64686 Ibllb-mol x x 29.64686 Ibl1b-mol x x 29.64686 Ibllb-moI x x 29.64686 Ibllb-mol x x 1000000 scf/MMsef Iblhr 

### I x 

### I 8760 hr/yr 

### I wt% Control % 0.15% x 96% 0.01% x 98% 0.18% x 98% 0.84% x 98% 0.10% x 98% 0.00% x 98%

x 

### 11 tonl2000 Ib 

## I

wt% Control % 0.15% x 96% 0.01% x 98% 0.18% x 96% 0.84% x 98% 0.10% x 98% 0.00% x 96%
x 

### 11 tonl?OOQlb 

### I



# • TPY = O.OOlblhr = 0.02 = 0.00 !blnr 

# . 0.00 = 0.00 !b/hr = 0.02 " 0.021b1hr = 0.09 " 0.00 Iblhr = 0.01 " 0.00 Iblhr 

# .. 0.00 " 0.00 Iblhr = 0.00 " 

## I 0.13 TPY 

## I

TPY " 0.00 Iblhr 

# .. 0.02 " O.OOlblhr 

### • 0.00 " 0.00 Iblhr 

## = 0.02 = 0.021b1hr 

### " 0.09 

### '" 0.00 Iblhr 

# .. 0.01 '" 0.00 !blhr = 0.00 " 0.00 Iblhf " 0.00 " 

### L 0.13 TPY 

### I


# •

# • • • •

Oakota-3 E&P Company, LLC , Patricia Charging 2·15H Pad Associated Wells: Patricia Charging 2·15HC. 2·15HD



## Casing Head Gas
Uncontrolled NOx (PTE): Nox:1 1,483 setlhr x 1 1.700 Stu/scr 0.17lblhr x

x 1Mmbtu/l.000.000 Btu 8760 hr!l!; x x 0.068 IbIMMStu 

### I
1tonl2OOO Ib 0.17 Iblhr 0.75 TPY NOx Created by Combustion (Actual): Nox:1 1,483 setlhr x 1 1,700 Stu/set 0.171b/hr x

x 1Mmbtu/l.000.000 Btu 8760 hrlyr x x 0.068 IblMMStu 1
1 tonl2000 Ib
__ 

### I = 0.17 Ib/hr _0.7j_TPyJ Controlled H2S (PTE): H.s:1 1,483 setlhr x 111379 scfllb-mole x 0.00 129.64886 IbJlb-mole 1 Ib/hr x x 8760**hr/~** wt% Conlrol% 0.00%1 x 

## I 98% 1

x 11 to",2000 Ib 0.00 0.00 Iblhr TPY Controlled H2S (Actual): H.s:1 1,483 scrlhr x 11/379 scfllb-mole x 0.00 129.64686 IbIlb-mole 1 Iblhr x x 8760 hr!l!; wt% Control % 0.00%1 x 

## I 98% 1

x 

### 11 10012000 Ib 0.00 0.00 Ib/hr TPY

# • • • 

# • Oakota-3 E&P Com LLC Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC. 2-15HD

S02 Created by Combustion (PTE):**5~~--sctlhr** 

### J )( 111379 scfAb·mole x 0.00 

### 129.64686 IMb-mole 

### 1
Ib/hr x x 8760 hrtyr wt% Control % 

## 0.00%1 x 

## I 98% 

## 1

x (!Jiii7¥OOO Ib0.00 0.00 Ib/hr TPY 

### 1 S02 Created by Combustion (Actual): 502

### 1 1.483 scflhr] x 

### 111379 scfAb·mole x 0.00 129.64686 1Mb-mole 1 Iblhr x x 8760 hrtyr wt% Control % 

## 0.00%1 x 

## I 98% 

## I

x 

### 11 tonl2OOO Ib - 

### 1 0.00 0.00 -iblhr TPY 

## Casing Head Gas ]

CO Created by Combustion (PTE): CO:C1/!3--sCfIhr] x 

### 1 1.700 Btu/scf 

### I r:::o:931b7hr:J x

x 1 Mmbtu/1,OOO,OOO Btu 8760 hrtyr x x 0.3701bIMMBtli 

### I
1tonl2000 Ib 0.93 4.09 Iblhr-­ I
TPY:J CO Created by Combustion (Actual): CO:I 1.483 scIlhr 

## J )( 1 1,700 Btu/sct I x 1Mmbtu/1,OOO,OOO Btu x 0.3701b1MMBtli I 0.93 Iblhr:J CO:-93lbihr] x 8760 hrtyr x 1tonl2000 Ib ••09 TPY 

### 1

# • 

# • • •

NOx. S02, PM, & CO emission factors are from AP-42 Table 13.5-1 and Table 1.4·2 (Emission Factors for Flare Operations and Natural Gas Combustion). 

# Oakota-3 E&P Company, LLC Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC. 2-15HD



## Casing Head Gas
PM Created by Combustion (PTE): PM:I 1,483 scflhr x 

### I 7.6 1b/1.000.000

### sa O.01lblhr x 8780**hr~** 0.01

x Iblhr 1 IOnl2OO0 Ib 0.05 TPY i PM Created by Combustion (Actual); PM:/ 1,483 scflhr x 

### I 7.6 1b/1.000,OOO scf 0.01 Iblhr x 8760**hrl~** 0.01
x Iblhr 1 tonl2OO0 Ib 0.05 TPY

# • • 

# • • Oakota-3 E&P Company, LLC Patricia Charging 2·15H Pad Associated Wells: Patricia Charging 2·15HC, 2·15HD



## Casing Head Gas [ REGULATED GREENHOUSE GAS EMISSIONSb C02 (PTE): C02 Entrained in the Produced Gas: Control % C02:! 1,483 scflhr:J x Ilf379scfnb-mole )( 129.64686 Ibllb-mole 

### 1 x 0.86%1 x 1 98% 

### I 1.00 IbIhr 1.00 Iblhr 

### :::J x 8760 hrfyr x 

### 11 ton12oo0 IbJ 4.38 TPV] C02 Created byCombustion:**c02: r---ua~----SCfiiirl**  x 1120,000.0 Ibtl,OOO,OOO set Cf?!:!2'b/fir! (-177.92 iblhi x 8760 hrfyr x 1 Ion/2000 IbJ 719.27 TPY Total C02Emitted (PTE):I 783.65 TPY ]

# • 

# • 

# • 

# •
[ Dakota-3 E&P Company, LLC 

# I
Patricia Charging 2-15H Pad Associated Wells: Patricia Charaina 2-15HC. 2·15HD 

# [ CasingHeadGas-
- - - -

# -:1

C02 (Actual): C02 Entrained In the Produced Gas: C02f 1,483-scrIi1Cl K 

### IIlmsCfflb-mole-1 K 

### I 29.64686 IbIlb-mole] wt% x 0.86%1 K Control % 1 98% , 

### I ­ 1.00
- Iblllr 

### 1 C02 Created by Combustion: 1.00 Ib/hr x 8760 hrlyr:J x IITonl2000l6
- J 

## C 4.38IPYl C02:C'l;4n- SCfIilr:J x [ffO;ooo:OT6/1JjOO,OOO 

### sa - - - 077.92 Ib/hr 

### 1- 177jj2 fb/hi
­ x 8760 hrlyr x 

## CJ3on12OOOT6

## d C779.27TPY -) Total C02 Emitted {A1lowable):C n:f.65tpy 

### -I Controlled CH4 (PTE): CH4:' 1,483 scf/hr x '11379 scfllb-mole x O.A 129.64686 IbIlb-mole 1 Ib/hr x x 8760 hrlyr wt% Control % 25.75%' x 

## I 98% 

## I

x 

## 11 tonl2000 Ib O.A 2.62 Iblhr TPY Controlled CH4 (Actual): CH4:' 1,483 scf/hr x '1/379 scfllb-mole x**_~** 

### I 29.64686 IbIlb-mole 

### I
JIltIlr:=:J x x 8760**hr~** wt% Control % 25.75%1 x 

## I 98% 

## I

x 

## '1 lonl2OO0 Ib O.A 2.62 Ib/hr TPY

# • 

# • • 

# • Dakota-3 E&P Company, LLC Patricia Charging 2·15H Pad Associated Wells: Patricia Charging 2·15HC. 2·15HD



## Casino Head Gas
N20 Created by Combustion (PTE): N20:1 1.483 scflhr 

### I x 

### I 2.2 Ib/1.000.000 scI 

### I = 

### I 3.26E-03 Iblhr 

### I 

## I 3.26E-03 Iblhr x 8760**hr~** x 1too/2ooo Ib = 

## I 8.15E-04 TPY 

## I I I 

## I I I

'C02 and N20 emission factors are from AP-42 Table 1.4·2 (Emission Factors lor Natural Gas Combustion). N20 Created by Combustion (Actual):
H20:1 1.483 scflhr 

## I x 

### I 2.2 Ib/1.000,OOO scI 

### I = 

## I 3.26E-03 Iblhr 

## I I 3.26E-03 Ib/hr 

## I x 

## I 8760**hr~** 

## I x 

## I 1ton/2OO0 Ib 

## I = 

## I 8.15E-04 TPY 

## I

# • • 

# • I 

# I Dakota-3 E&P Company, LLC 

# •

Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC, 2-15HD 

# I Heater Treater Burnera 

# I

Burner Rating 

### ! 1,500,000 Btulhr !Thls burner rating reflects the combined size ofall ofthe proposed heatertreater burners atthefacility.
HOx:1 0.10 I67MMStu x 1.50 MMBtulhr ! CO:f47 -Ibltlr -! (o.1471lb/hr -] x 8,760 hrlyr x 11 ton 12000 Ib

### J '" I ,U144 -TPY -, co:! 0.08 I6IMMB1i.I x 1.50 MMBtulhr 

### 1 0.124 Iblhr- -] [ lr.12l671i-r- -, x 8.760 hr!yr x 

### 1 1ton 12000 Ib 

### I:: 0.541 TPY 

## I
S02:!5.88E..()4 IblMMBtu x 1.50 MMBtulhr! COJlO1 -Iblfir - I (8.82E-04 Iblhr x 8,760 hrfyr J( O]fnT2000Tb 

### I =0.004 TPY
PM:I 0.01·· IbIMMStu x 1.50 MMBtulhr 

### I I-Un Iblfir
. 

### I ( 0.0'1 167f1r
- 

### -I x 8,760 hrlyr x 

### ! 1ton /2000 Ib , "" 0.049 TPY -.

# • • • 

# • I Oakota-3 E&P Company, LLC
Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC, 2-15HD

VOC:!Q]f1-lbiMMBtO x 1.50 MMBtulhr! 

### = 0.008 Iblhr 

## J 

## om Ib/hr 

### J x 8.760 hrlyr x ! 1ton 12000 Ib 

### ! = 0.035 TPV 

# I Heater Treater Burnera 

# I

HAP:!**O~2-lb/MMBtUJ** x 1.50 MMBtulhr! 0.003 Ib/hr 

### 1**!2Jl.!E~03** 16th" x 8.760 hrlyr x [IJQi1T20lXH6] 0.012 TPY]
C02!fll.64TlbiMMBIO x 1.50 MMBtu/hr! 176.471 Iblhr 

### J [U61:+02lbihr- 

### 1 x 8.760 hriyr x '11on 12000Ib! 772.941 TPY­

# • • 

# • • I - - -- 

# I Oakota-3 E&P Company, LLC
Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC. 2-15HD



## Heater Treater Burnera 

# I**'~**
CH4:1 0.007 Ib/MMBtu 19.92E-03 Iblhr
H20:' 0.001 IblMMBtu 11.98E-03 Iblhr )( )(

)( )( 1.50 MMBtulhr 

## I 8,760 hr!f )( 11 ton liOoo IbI

1.50 MMBtulhr I 

### 8.760 hrlyr )( '1Ion I 2000 Ib 

### I 0.010 Iblhr ' 0.043 TPY
0.002 Iblhr 0.009 TPY 

### - I °NOx, CO, C02. & VOC Emission Factors are from AP-42 Table 1.4·1 and 1.4·2 (Emission Factors for Nitrogen Oxides (N20) and Methane come from Table C-l of Subpart W).
,-**-O~** -OOxTPY-, 

## C -1[54- COTP'f 

### I 

# c 0.00 S02TPV 

### C 0.05 PMTPYJ 

# c - 0.04 ­ VOCTPYr:::m---.:iAPTPV

### I I - 772.94 'C02'(PV ' 

### C -0:04 -CH4TPy-'1 0:0'1 N20TPY

# • • 

# • 

# •**~** 

# .. Oakota-3 E&P Company, LLC**~** Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-19HCL 2-15HD 

# Truck Loadout Emission Calculation II Saturation Vapor Molecular Temp + Load Loss Factor (S) Pressure (P) Weight (MW) 460 Ib/1000 gal 12.46 

### I x 

# I 0.60 

# I x 

# I 2.30 

# I x 

# I 42.14 

# I I 

# I 510.00 

# I = 

# I 1.42

LL Truck Load Load Time Total Gas Ib/1,000J,tal Rate bbllhr hrs gallbbl Emissions Iblhr 1.42 

### I x 

# I 180.00 

# I I 

# I 1.00 

# I x 

# I 42.00 

# I = 

# I 10.74 

# I LL Annual Emissions Uncontrolled Ib/1,000 gal bbllyr**~allbbl** Ib/ton TPY C3+VOC tpv 1.42 

### I x 

### I 186784.92 

### I x 

# I 42.00 

# I I 

# I 2000.00 

# I = 

# I 5.57 

### I 4.12 

# I voe Emissions Uncontrolled Control % TPY '--- 4.12 

## .J L100% 

# J I**O.~** 

# I**L~oo_1** 

## ======

# • • • 

# •

===-= LL Annual Emissions Uncontrolled Ibl1,OOO gal bbllyr aallbbl Iblton TPY**HAPst~** 1.42 

### I x 

### I 186784.921 x 

# I 42.00 

# I I 

# I 2000.00 

# I = 

# I 5.57 

# I I 0.06 HAPs Emissions Uncontrolled Control % TPY 0.06 

### I 100% 0.00 0.00 

# I I I 

# I I 

# I i LL Annual Emissions Uncontrolled Ibl1,OOO gal bbllyr gallbbl Iblton TPY C02tDY 1.42 1 x 

### I 186784.921 x 

# I 42.00 

# I I 

# I 2000.00 

# I =

# I 5.57 

### I 0.01 

# I CO2 Emissions Uncontrolled Control % TPY 0.01 

### I 1000 k 0.00 0.00 1 1 

# I I 

# I I LL Annual Emissions Uncontrolled Ibl1,OOO gal bbllyr aallbbl Iblton TPY CH4tDY 1.42 

### I x 1186784.921 x 1 42.00 1 I 

# I 2000.00 

# I = 

# I 5.57 

# I I 0.11 CH4 Emissions Uncontrolled Control % TPY 0.11 

### I 1 100% 

### I I 0.00 

### I I 0.00 

### I

# • 

# • II Dakota-3 E&P Company, LLC 

# I

# I II RICE Input Data 

# I

Combined Diesel Engines Hours ofOperation Maximum HP Rating NOxg/hp-hr CO alhp..hr 802 g/hP-hr PM glhp-hr !VOC alhp..hr HAP QJbh-hr C02g1bh-hr CH4 a/bh-hr N20 alho-hr



# • 8760 550 1.49E+OO 2.61E+OO 4.52E-06 4.85E-06 1.42E-01 1.02E-06 2.54E-03 2.10E-02 4.20E-03



# • Description EnglntII ...umedto operate 8,780hOUri peryear. IManufacturerGUlrlntee (40CFR 13 SubpartIDlrequll'llllentl), ...AltachmentF

.....uflcturtrGuerlntee (40CFR 13SubpartIRlrequll'llllentl), ... AttachmentF "P-42Table 3.3-1 AI42Table3.3-1 ManuflcturerGUlllntee {40 CFR 13 Subpart1mrequllll'llllltll, ... AtblchmentF 

### 1AP-42Table 3.3-1 

### 1AP-42Table 3.3-1 140CFR98 Sub.,artC,Table Co2 140CFR98 Sub.,artC,Table Co2 Recycle Pump Description Hours ofOperation 8760 EnglntlIa..umldto operate 8,780 hOUri pery... Maximum HP Ratina 16 IManuflcturer'lmulmumhp rating. NOx Q/hp..hr 4.99E+00 

### 1AP-42Table 3.3-1 CO-glhp..hr 3.16E+00 

### 1AP-42Table3.3-1 802 a/ho-hr 2.68E-01 

### 1AP-42Table 3.3-1 PM alhP-hr 3.27E-01 

### 1AP-42Table 3.3-1 IVOCglhp.hr 9.80E+OO 

### 1AP-42Table 3.3-1 HAP alho-hr 2.20E-01 

### 1AP-42Table 3.3-1 C02 g/bh-hr 4.90E+02 

### P-42Table 3.3-1 CH4 alho-hr 2.10E-02 40CFR98 SubpartC,TableCo2 N20 alho-hr 4.20E-03 40CFR98 SubpartC,TableC.z

# • • • 

# •

ENGINE #1 [ 55f:J MAX HP !i2Ii. 1.49E+OO Ii!!:!P-HRI x 550 HP x 11 Ib 1453.6**~rams** 1.81E+OO Iblhr 

### I x 8160 hr!t! x (1 ton 12000]lil 

### =

### P .93E+OONOx!PiC]**~** 2.61E+OO Ii!!:!P-HRI x 550 HP x 11 Ib I 453.6 I.!rams 3.11E+OO Iblhr 

### I x 8160 hr!t! x 11 ton 12000lbl I 1.39E+01 CO TPY 802: 4.52E-06 I!!HP-HRI x 550 HP x 11 Ib 1453.6I!rams 5.48E..08 Iblhr x 8160**hr~** x 1ton I 2000lb

### I 2.40E-05 502 TPY PM: 4.85E-06 I!!!:!p-HRI x 550 HP x 11Ib/453.6I!rams 5.88E..08 Iblhr x 8160 hr!t! x 1 ton I 2000lb

## I 2.58E-05 PM TPY VOC: 1.42E-01 li!!:!p-HRI x 550 HP x 11 Ibl 453.6 srams 1.12E-01 Iblhr x 6160 hr!t! x 1 ton 12000lbl 7.53E-01 voc TPY HAP; 1.02E-06 Ii!!:!P-HRI x 550 HP x 11 Ib 1453.6srams 1.24E..08 Iblhr x 8160 hr!t! x 1ton 12000lbI 5.42E-06 HCHO TPY**~** 2.54E-03 S/HP-HRI x 550 IHP x 11 Ib 1453.6**~rams** 3.01E-03 Iblhr x 6160 hr!t! x 1 ton 12000lbI 1.35E-02 CO2 CH4: 2.10E-02 I!!!:!p-HRI x 550 HP x 11 Ib 1453.6**~rams** 2.55E-02 Iblhr x 8760 hr!t! x 1ton 12000lbI 1.12E-01 CH4**~ 4.~E-C)l**  glHP-I-iRI x 550 HP x 11 Ib 1453.6 grams 

### = 5.09E-03 Iblhr x I 8760_ hrlyr x 1ton 12000lb I 2.23E-02 N20 

# Oakota-3 E&P Company, LLC
Patricia Charging 2-15H Pad Associated Wells: Patricia Cha!9l!!9.2-15HC, 2-15HD 

# C Reciprocating Engine Emissions -_. - -- - _.. - - - 

# I

# • • 

# • [ Oakota-3 E&P Company, LLC
Patricia Charging 2·15H Pad Associated Wells: Patricia Charging 2·15HC, 2·15HD 

## Reciprocating Engine Emissions

## -~ ENGINE #2 16 IMAXHP

NOx: I 4.99E+OO gIHP-HR! x 16 HP x 11 Ib 1453.6 srams

### I x 0.18 fb/hr x 8760 hr/;t! x 1ton I2000fb

### I = 7.71E-Ol NOxTPY] !<2;. I 3.16E+00 gIHP-HR

### I x 16 HP x 11 fb 1453.6 §!rams

## I x 0.11 fblhr x 8760 hr!;t! x 1ton I 2000fb

## I 4.88E·01 COTPY §.Q1;, I 2.88E-01 g/HP-HR! x 16 HP x 11 fb 1453.6 Ilrams 

## I 9.46E-03 fblhr x 8760 hr!;t! x 1ton I2000lb

## I 4.14E-02 502TPY eM.;. 

### I 3.27E-01 g/HP-HR! x 16 HP x 11 fb I 453.6 IIrams 

## I 1.15E-02 fb/hr x 8760 hr!;t! x 1ton I 2000fb

## I 5.05E-02 PM TPY 

### I 9:&OE+OO-

### 91 HP-HR] x 16 HP x 11 fb 1453.6 Ilrams x 0.35 fblhr x 8760 hr!;t! x 1 ton 12000lbl 1.51E+OO VOC TPY .!:!!e;. I 2.2OE.:o1 gIHP.HR! x 16 HP x 11 Ib I 453.6I1rams 0.01 Iblhr x 8760 hr!;t! x 1ton 12000fb

## I 3.40E·02 HAP TPY I '(90E+02 Q/HF>:f"m x 16 HP x 11 lb I 453.6I1rams 1.73E+01 lblhr x 8760 hr!;t! x 1ton 12000lb

## I 7.57E+Ol C02 TPV CH4: 

### I 2.10E-02 gIHP-HRI x 16 HP x 11 fb I 453.6 §!rams 7.41E-04 Iblhr x 8760 hr!;t! x 1ton I2000lb

## I 3.24E-03 CH4 TPY N20: I UOE-03 g/HP.HR! x 16 HP x 

### Ii Ib I 453.6 grams 1.48E-04 Iblhr x**87~** j1r/yl' x 1ton I2000fb

### I 6.49E·04 N2Q TPiJ



# •

# • 

# • • 

# •

Oakota-3 E&P Company, LLC
Patricia Charging 2-15H Pad Associated Wells: Patricia Charging 2-15HC, 2-15HD 

## Reciprocating Engine Emissions

TOTALS [!]OE+ilONOiTPY--- 

### :J 1.44E+01 CO TPY 4.14E"()2 S02TPV 5.08E"()2 PM TPY 2.27E+OO VOC TPY 3.40E"()2 HAP TPY 7.57E+01 C02 TPY 1.15E..()1 CH4 TPY 2.30E"()2 H20 TPY

# •
ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS

• E&P Tanks Emission Summary • E&P Tanks Linear Relationship (Emission Factor) 

# •



# •

Dakota-3 E&P Company, LLC. NSR Synthetic Minor Application WEP211324 

# •

### Mandaree Field 1000 BOPD wt% ****************************************************************************************** 

## * project Setup Information 

### * ****************************************************************************************** 

### project File : y:\projects\wil1iams Exploration & Production WEP\WEP211324 Ft. Berthold IR well work\E&p Tanks\Mandaree Field 1000 BOPD.ept Flowsheet Selection oil Tank with Separator calculation Method RVP Distillation Control Efficiency 100.0% Known Separator Stream Low Pressure oil Entering Air Composition No Filed Name Mandaree well Name Cross 2-13H and patricia charging 4-15H Averages Permit Number Dakota-3 E&P Company, LLC Date 9/24/2010 

# • ****************************************************************************************** 

### * Data Input 

### * ****************************************************************************************** 

### separator pressure 51.00[ps;g]**sep~rator** 

### Temperature 82.50[F] Amblent Pressure 14.70[ps;a] Ambient Temperature 70.00[F] c10+ SG 0.8000 CI0+ MW 235.14 LOW Pressure oil
---------------------------------------------------------------------­ NO. component wt % 1 H2S 0.0014 2 02 0.0000 3 C02 0.0042 4 N2 0.0015 5 c1 0.0320 6 c2 0.3654 7 c3 1.2089 8 ;-C4 0.3443 9 n-C4 1.5191 10 ;-c5 0.6508 11 n-C5 1.2185 12 c6 1.3933 13 c7 

### 6.7524 14 C8 15.9338 15 c9 14.3170 16 C10+ 53.7971 17 Benzene 0.0479 18 Toluene 0.0997 19 E-Benzene 0.0600 20 xy1enes 0.3998 21 n-C6 1.4864 22 224Trimethy1p 0.3663 

# • sales oil
----------------------------------------------------------------------------­ production Rate 1000[bb1/day] Days of Annual operation 365 (days/year] API Gravity 41.85 Reid vapor Pressure 5.90[ps;a] ****************************************************************************************** 

### * calculation Results 

### * ******************************************************************************************



### -- Emission Summary
---------------------------------------------------------------------­ Item Uncontrolled Uncontrolled [ton/yr] [lb/hr] page 1---------------------------------------------------------------- E&P TANK Total HAPs 8.550 1.952 Total HC 812.744 185.558 vocs, C2+ 796.480 181.845 VOCs, c3+ 612.595 139.862 page 1 

# •

# • Mandaree Field 1000 BOPD wt% uncontrolled Recovery Info. vapor 40.2300 [MSCFD] HC vapor 40.0300 [MSCFD] GOR 40.23 [sCF/bbl] Emission composition
-----------------------------------------------------------------­ No component uncontrolled uncontrolled [ton/yr] [lb/hr] 1 H2S 0.689 0.157 2 02 0.000 0.000 3 co2 2.160 0.493 4 N2 0.786 0.179 5 cl 16.264 3.713 6 C2 183.886 41.983 7 c3 375.375 85.702 8 i-C4 37.149 8.482 9 n-C4 112.787 25.750 10 i-C5 17.863 4.078 11 n-C5 24.862 5.676 12 c6 8.648 1.974 13 c7 13.803 3.151 14 C8 10.281 2.347 

# • 15 c9 3.270 0.747 16 C10+ 0.004 0.001 

### 17 Benzene 0.234 0.053 18 Toluene 0.136 0.031 19 E-Benzene 0.027 0.006 20 xylenes 0.156 0.036 21 n-C6 7.394 1.688 22 224Trimethylp 0.604 0.138 Total 816.378 186.388

-- Stream Data
--------------------------------------------------------------------------­ NO. component MW LP oil Flash oil sale Oil Flash Gas W&S Gas Total Emissions**~% ~% ~% ~% ~% ~%**  1 H2S 34.80 0.0014 0.0010 0.0000 0.0873 0.0856 0.0861 

### 2 02 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 3 C02 44.01 0.0042 0.0020 0.0000 0.4818 0.1765 0.2642 4 N2 28.01 0.0015 0.0001 0.0000 0.3044 0.0123 0.0962 5 cl 16.04 0.0320 0.0079 0.0000 5.2226 0.6866 1.9891 6 C2 30.07 0.3654 0.2356 0.0039 28.3624 20.1288 22.4930 7 c3 44.10 1.2089 1.0468 0.4786 36.1613 49.8497 45.9192 8 i-C4 58.12 0.3443 0.3257 0.2757 4.3503 4.6218 4.5438 9 n-C4 58.12 1.5191 1.4623 1.3185 13.7647 13.8076 13.7953 10 i-c5 72 .15 0.6508 0.6432 0.6257 2.2771 2.1480 2.1850 11 n-C5 72.15 1.2185 1.2094 1.1888 3.1795 2.9854 3.0410 12 c6 86.16 1.3933 1.3945 1.3984 1.1369 1.0640 1.0850 13 c7 100.20 6.7524 6.7753 6.8342 1.8207 1.7133 1.7442 14 C8 114.23 15.9338 16.0015 16.1730 1.3430 1.2744 1.2941 15 c9 128.28 14.3170 14.3815 14.5440 0.4133 0.4189 0.4174 16 CI0+ 235.14 53.7971 54.0465 54.6758 0.0006 0.0005 0.0006 17 Benzene 78.11 0.0479 0.0480 0.0483 0.0298 0.0281 0.0285 18 Toluene 92.13 0.0997 0.1001 0.1011 0.0174 0.0165 0.0166 19 E-Benzene 106.17 0.0600 0.0603 0.0610 0.0035 0.0032 0.0033 20 xylenes 106.17 0.3998 0.4016 0.4059 0.0196 0.0187 0.0191 

# • 21 n-c6 86.18 1.4864 1.4889 1.4959 0.9466 0.8874 0.9045 22 224Trimethylp 114.24 0.3663 0.3677 0.3711 0.0772 0.0726 0.0739 MW 143.08 144.90 148.98 39.02 43.55 42.14 Stream Mole Ratio 1.0000 0.9829 0.9448 0.0171 0.0381 0.0552 Heating value [BTU/SCF] 2225.52 2481.29 2401.97 Gas Gravity [Gas/Air] 1.35 1.SO 1.45 Bubble Pt. @ 100F [psia] 32.28 20.39 7.37 page 2---------------------------------------------------------------- E&P TANK RVP @ 100F [psia] 15.35 12.04 6.01 spec. Gravity @ 100F 0.677 0.678 0.680
Page 2 

# •Oil StorageTank Flashing Emissions Calculation Methodology E&P Tanks Linear Relation between Production (bbls/day) and Emissions (tons/yr) Emission estimates are based on using the E&P TANK V2.0 Model, RVP Distillation Column As shown below, the E&P Tanks summary output has a linear relationship with the production rate of the oil with the given inputs listed below. Inputs: Low pressure oil from average of 2 representative Mandaree Field Dakota-3 Wells Separator: 51 psig, 83 degF Flash Valve: 13.7 psia, 50 degF Sales Oil: API Gravity 41.9, Reid Vapor Pressure 5.90 pSia, 365 days/year 

# • Outputs: Oil Production Rates (bbVday) (P) 0 50 100 300 1000 Emission (tonslyr) Total HC 0 40.6372 81.2744 243.8232 812.744 VOCs, C3+ 0 30.62975 61.2595 183.7785 612.595 Total HAPs 0 0.4275 0.855 2.565 8.55 VOC (C3+) Emission Factor: 0.6126 tpy/BOPD HAP Emission Factor: 0.00855 tpy/BOPD 

### Tank Emissions by Production Rate

-+-Tolal HAPs _VOCs,C3+ -linear(Tolal HAPs) -linear(VOCs, C3+}
bbl/day 

# • 700 600



# ... 500 

# I 400 300 0 200 

# - 100 0 0 500 1000 1500



# •

# •
ATTACHMENT D: REPRESENTATIVE LOW PRESSURE OIL 

## ANALYTICAL DATA



# I 

# •

Dakota-3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324 

# •

# •
Labul'atOJl • Gas Measurement Emissions Testing • Sample CollectIon A2lA Aa:n:dited • NElAf' Au:n:dUed • ErA CertlOed 29 Country**Acr~** Rd. Riverton. \lOy 82.501 • Toll F..,e: (866) 98!.-0866 • E-.....II: Inlow I',,,dslon-Labs,c:om • Online, W'WW.I',ec:lslon-Labs.com 

### EXTENDED HYDROCARBON (GLYCALC) UQUID STUDY Company
.................... ZENERGY Lab Number
................ CR-10330 Study Number
.......... CR-2 Date Sampled
.............. 7-15-2010 Date Tested
............. 7-23-2010 

# • Sample Identification
.................... CROSS 2-13 H CRUDE Oil Sample Location
.......... MONTANA. Sample Pressure
......... 22 PSIG Sample Temperature
.... 95 F Type Sample
............... SPOT County
...................... DUNN Test method
................ GPA-2286 Sampling Method
........ YZ PISTON Components Mole % Weight % Liq. Vol. %



# • Hydrogen Sulfide
.......... 0.003 0.001 0.001 Oxygen
...................... 0.000 0.000 0.000 Carbon Dioxide
............ 0.013 0.004· 0.004 Nitrogen
..................... 0.007 0.001 0.001 Methane
..................... 0.180 0.021 0.050 Ethane
....................... 1.602 0.342 0.709 Propane
..................... 4.036 1.264 1.839 iso-Butane
.................. 0.855 0.353 0.463 n-Butane
.................... 3.974 1.640 2.072 iso-Pentane
................ 1.378 0.706 0.833 n-Pentane
................... 2.569 1.316 1.540 Hexanes
..................... 2.510 1.536 1.707 Heptanes
.................... 10.694 7.610 8.159 Octanes
..................... 19.351 15.699 16.394 Nonanes
..................... 17.072 15.551 15.886 Decanes+
................... 31.435 51.099 47.376 Benzene
...................... 0.093 0.052 0.043 Toluene
....................... 0.166 0.109 0.092 Ethylbenzene
............... 0.104 0.078 0.066 Xylenes
....................... 0.618 0.466 0.397 n-Hexane
.................... 2.798 1.712 1.903 2,2,4-Trimethylpentane
... 0.542 0.440 0.466 TOTALS
..................... 100.000 100.000 100.000 

# •

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.486 0.910 1.011 3-Methylpentane 1.024 0.627 0.696 n-Hexane 2.798 1.712 1.903 2.2,4-Trimethylpentane 0.542 0.440 0.466 Benzene 0.093 0.052 0.043 Toluene 0.166 0.109 0.092 Ethylbenzene 0.104 0.078 0.066 m-Xylene 0.066 0.050 0.042 p-Xylene 0.436 0.329 0.280 o-Xylene 0.116 0.087 0.074

API GRAVITY AT60/60 F, calculated
........................................................................ SPECIFIC GRAVITY AT 60/60 F, calculated
.............................................................. RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION
............................. .. AVERAGE MOLECULAR WEIGHT
.......................................................................... AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION
........................ .. TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated
.............................................. .. AVERAGE BOILING POINT, F,
................................................................................ CUBIC FEET OF GAS I GALLON OF LIQUID, as Ideal Gas
......................................... . BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated
............................................... .. LBS I GALLON OF LIQUID, calculated
......................................................................

,,' "} HI< I'. \l.[ ( '\U I I\TI\;',:· Pl.RIOR\H-D tSI'.(. PHY:;l( \1 (( l",,,T /I'-.T' fR( )\1 "P'I ,14', (Ill IHI L\lll I" 01 PII),,!( -\1 (**(,:,~n',T'>** J( IR HY[)R( )(-\R!l( I"S

# -,,,I) ('THI,R ( (·;.lpotl"[1' OJ I'.TI',RESl 

# •

60.3 0.7378 0.7958 140.803 228.881 33.400 299.063

19.106 122456.887 6.152 

# •

•

## -------------

- 

# • EXTENDED HYDROCARBONLIQUID STUDIES ( FRTIII(\TF ()J"**\~** 

### \1 Y:-;I:-­ Company.............. .. PRECISIONANALYSIS Lab Number............. CR-10330 StudyNumber.......... .. CR-2B Date Sampled............. 7-15-2010 DateTested.............. 7-22-2010 Sample Identification..•..........••. ZENERGY
- CROSS 2·13 H CRUDE OIL 

# • Sample Location........ . MONTANA. Sample Pressure........ .. N/A Sample Temperature..•• N/A Flowrate....•....•...•••.•. N/A County.................... . DUNN 1-QUART Test Method.............. VARIOUS Sample Container........ BOTTLE TEST PERFORMED RESULTS API GRAVITYAT 60/60 F (ASTM D-287), observed...................... 42.5 SPECIFIC GRAVITY AT 60/60F (ASTM D-1657), calculated.......... 0.8132 REIDVAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 5.2 PSIG TOTALSULFUR CONTENT (ASTM D-5453), PPMW................ .. 658.98 PPMW TRUEVAPOR PRESSURE (ASTM D-2889), PSIA AT 100 F ........... N/A BASIC SEDIMENTANDWATER CONTENT, % BY VOLUME.... N/A COPPER STRIP CORROSION (ASTM D-130), 1HOURAT 100 F........... N/A FREEWATEa,observed........................................................ . N/A 

# • NOTATIO:S; 

## ".u TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOG\ Ol'TLINED BY rHE AMERICAN SOCIETI FOR rESTING AND MATERIALS (ASTM)



# •

# • l.4Ioo,alorJ Ga! l'Ie...,."re.."l>U,1 [minto... luling >**5a"'p.I~** CoII""lk", Chromatogram Cross 2-I3H C:\GCsolution\DRO\DRO Data\08-2010\08-0\-201 O\Cross 2-I3H.gcd
- Channel \ 50000 100000 \ 200000 250000**~··~~~~~'---------·----·~--2.6671** bL-­

__ 3.6321**----·------··-----~·--·4.0691** 

## ====-U(.l8..J:__________5.6081 Decane (CIO)

------­ 5.947 1**:r.:'::'c--~-~·~----------7.0831 c=~-------------9.7241** **~,.;;...--------** 10.9111 --------12.0311

-----­ 13.0881

__fr+---- 14.089!

15.947 ! G-'erphenyl Intensity



# •



# •

:5' 

# • 3

# •
Laboratory •**Ga~Mea!;urcmcnt** 

# PREIPISIQ._ Emissions Testing • Sample Collection 

### WfJ 1

## ,ttASi§·f1tt\a:I

## At\i;l2§i§.li

## ffla

## A UitUhffll

### ~~AN~_ 

## ........ 29 c.ountry Acres Rd,**RI~"rton,** "" alSOI • Toll Fn:
.. ' 866 ' ( )**98~-0866** • E·...all: Infoii' "r"clslon·Labs.com • Onll..-'**~.** b "_1**La~'** ......**---~** ..."C_ ou" .,.,.,.(;0ftI 

### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY



### UNITED STATES ENVIRONMENTAL PROTECTION AGENCY Region 8Air Program FEDERALMINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

# iEPA CheckList
- Application for New Construction (FonnNEW) 

### Please check all that apply to show how you are using this form
• Proposed Construction ofa New Facility 

## o Proposed Construction ofNew Equipment at an Existing Facility 

## o Proposed Modificationofan Existing Facility 

## o Other
- Please Explain Use ofthis information request form is voluntary and not yet approved by the Office ofManagement andBudget The following is a check list ofthe type ofinformation that Region 8will use to process information on your proposed project. While submittal ofthis form is not required, it does offer details on the information we will use to complete your requested approval and providingthe information requested may help expedite the process. Use ofapplication forms for this program is currentlyunder Office ofManagement and Budgetreview and these information request forms will be replaced/updated after that review is completed. 

### Please submit informationto following two entities: TheTribal Environmental Contact for the specific reservation: Minor NSRPermittingCoordinator U.S. EPA, Region 8 Ifyou need assistance in identifying theappropriate Tribal 1595 Wynkoop Avenue, 8P-AR Environmental Contactandaddress, pleasecontact the EPA Denver, CO 80202·1129 Region 8 Tribal AirCoordinator: Alexis North, EPA Region 8 Tribal 

### Air Coordinator 303-312-7005 north.alexis@epa.gov 

### A. GENERAL FACILITY INFORMATION 1. (a) 

### Company Name Dakota-3 E&P Company, LLC (b) 

### OperatorName Dakota-3 E&P Company, LLC 2. 

### Facility Name Patricia Charging 2-15H Pad

3. Type ofOperation Oil and Gas Production 6. NAICS Code 

### 4. Portable Source? 

# o Yes 5. Temporary Source? 

# o Yes 7. SIC Code 

### I2i;1 No 

### I2i;1 No

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.272 0.734 0.826 3-Methylpentane 0.908 0.524 0.590 n-Hexane 2.204 1.271 1.431 2,2,4-Trimethylpentane 0.387 0.296 0.317 Benzene 0.085 0.044 0.038 Toluene 0.148 0.091 0.078 Ethylbenzene 0.060 0.043 0.037 m-Xylene 0.058 0.041 0.036 p-Xylene 0.298 0.212 0.183 o-Xylene 0.117 0.083 0.072

API GRAVITYAT 60/60 F, calculated
....................................................................... . SPECIFIC GRAVITY AT 60/60 F, calculated
.............................................................. RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION
.............................. . AVERAGE MOLECULAR WEIGHT
.......................................................................... AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION
........................ .. TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated
.............................................. .. AVERAGE BOILING POINT, F
................................................................................. CUBIC FEET OF GAS I GALLON OF LIQUID, as Ideal Gas
......................................... . BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated
................................................ . LBS I GALLON OF LIQUID, calculated
.................................................................... ..

rill I \BII-­ (,I**!'IIY~/(** \1 ( \';q**r~** 1< 'R HYDR( \( -\RB(**J"~** 

## -\'D (lTHU{ ( ( )\11'( 't '-I), (,[ 1"- 11- RFS! n, !III" ITI R-\I (,\, I'DldR'l 57.8 0.7475 0.8050 149.417 241.399

46.319 314.836

18.857 122700.693 6.232

# • EXTENDED HYDROCARBON LIQUID STUDIES
Company........••...... ZENERGY Lab Number.•....•.....• CR-10330 Study Number.•••....•... CR-3B Date Sampled.•...•....••. 7-15-2010 DateTested••.•.••..•.•.. 7-22-2010 Sample Identification...•...••.•..•.. PATRICIA CHARGING 4-15 H CR1JDE OIl 

# • Sample Location.•..••.•. MONTANA. Sample Pressure.......... N/A Sample Temperature.. .. N/A FIowrate................. .. N/A County.................... . DUNN I-QUART Test Method.............. VARlOUS Sample Container........ BOTfLE TESTPERFORMED RESULTS API GRAVITY AT 60/60F (ASTM D-287), observed...................... 41.2 SPECIFIC GRAVITYAT60/60F (ASTM D-1657), calculated.......... 0.8193 REIDVAPOR PRESSURE (ASTM D-323), PSIGAT 100 F.............. 6.6 PSIG TOTALSULFUR CONTENT (ASTM D-5453), PPMW................ .. 940.25 PPMW TRUEVAPORPRESSURE (ASTM D-2889), PSIA AT 100 F ........... N/A BASIC SEDIMENTANDWATER CONTENT, % BYVOLUME.... N/A COPPERSTRIPCORROSION (ASTM D-130), 1HOURAT 100 F........... N/A FREEWATER, observed........................................................ . N/A

NOTATION: AU. TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDlLNCE TO .\fETHODOLOG) 

# • Ol'TlINED B) THE 'l.MERICAN SOCIETY FOR TESTING'"ND MATERIAl.S**(AST~i)**



# •I.A;D-..)'-"'iOf)**{.Ja~** ft'lta5..n{rY,ini [ ..."'ohm, '.."lIng , S;in.plt CnU.,OIOIi _ildMiftffE&iULiJii&,I!f't°';'ffimw. 

# •

Chromatogram PC 4·151-100 C:\GCsoJution\DRO\DRO Data\08-201O\08-01-20IO\PC 4·15 1-100.gcd
- Channell 

## o 50000 100000 150000 200000 250000 Intensity**~.~.~.~_--,;;;;..c;..:-.** ___ ________-
____. 2.6671 .;)!w"-
__ 3.6351**~~-------,.---------.-** 4.0701 

### ====..5.5.lll.L

_________._ 5.6101 Decane (CIO)**-~-~----------** 7.0841 

# •**~===8.634!--··---·---** ..- 8.4531**~~-----------** 9,7251**~-------** 10.913/

-------- 12.0311

----- 13,0881 --til_<+-- 14,0911

15.9501 'HeIphenyl


# •

:;' 

# • 3

## ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS

I

# •

Dakota-3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324 

# •

# • 

# • • •

A' 

## M d A 

### G 

### C 

# . I Data (Coli , 

### d 10/11/2011) , 

# ... 

# ....1­
"""'.o...e COl IWI") 44.010 Nit"",
... IWt%) 28.013 HZS IM_, 34.081 Cl 1Wt%, 16.043 a IWt%, 30.069 a IWI", 44.096 14:4 1Wt%, 58.122 "4:4 1Wt%) 58.122 14:5 1Wt%1 72.149 n.cs 1Wt%) 72.149 (6 IWt%I 86.180 C1 1Wt%, 101.21 CI+ 1Wt%1 114.23 1Wt%, 18.112 ToIue
... IWt%) 92.140 E_
..... IWt%I 106.110 leyl..... IWt%1 106.160 n·.....". IWt%I 86.180 ...-thy! pent.... 114.230 

# ........ V.h,. IlItu/seII .pe.Iff< Gravity c..lculat4ld ""I
. MotHuiat Weicht Alishill Fa.lS-9 1.161 3.626 0 36.543 24.689 18.ll7 1.949 5.713 1.092 1.159 1.621 1.321 0.545 0.251 0.264 0.014 0.462 0.657 0.004 1462.236 0.8862 25.666 I \11101121-34 0.836 2.541 0 33.17 23.484 18.569 2.543 7.523 2.219 3.884 2.219 1.481 0.166 0.085 0.11 0.006 0.026 1.138 0 1558.1 0.9345 27.065 I e ••rs Tail 32-29 0.724 1.414 0 20.353 26.461 28.74 3.763 10.995 1.776 2.491 1.158 0.773 0.498 0.038 0.216 0.014 0.05 0.536 0 1796.8 1.0738 31.101 at2·1 0.81 1.352 0 19.208 2L796 27.321 4.559 14.169 2.623 3.749 1.845 1.209 0.121 0.D75 0.097 0.007 0.021 0.975 0.002 1874.11 1.1253 32.591 Skunk Creek 1·23 0.693 3.545 0 25.407 22.578 25.451 3.399 11.195 2.037 2.674 0.515 0.769 0.487 0.04 0.ll7 0.016 0.066 0.771 0 1663.5 1.0141 29.37 Nathan H.le 3·18 0.873 3.471 0 32.094 16.795 17.765 3.156 11.786 2.666 3.871 2.76 2.453 0.109 0.53 0.215 0.01 0.038 1.405 0.002 1602.8 0.9765 28.281 High H.wk4-9 0.681 0.471 0 13.456 30.949 33.204 3.787 11.001 1.714 2.273 0.941 0.252 0.605 0.043 0.19 0.011 0.049 0.375 0 1945.1 1.1551 33.454 Average'! I 0.1163 I 2.346 I 0.000 I 25.141 I l3.an I 24.195 I 3.308 I 10.340 I 2.018 I 2.951 I 1.581. I 1.183 1 O.3!2 LJI·IS!,**1~17U** 0.011 0.101 0.837 0.001 1100.387 1.02' 29.64686 Note:An calculations were preformed by Precision Anatvsis using physkalconstants from**GPA~2145-09,**

# •

29 Count'}' ACflts Rd, Riverton, WY 82501 Onlln., _.Preclalon·Labs.com E-mall.ln.o(!iPreclalon·Labs.com Toll Fre. Numbe.. (866) 985..0866

Client: BISON ENGINEERING Sample 10: AliSIA FOX 16-9 Unique#: SampleTemperature: 62 DEG F Sampled By: TC County: DUNN Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample: 10/11/2011 10/11/2011 

# • 20 PSI ONLINE

Components Mole % Weight % Liq.Vol. % Carbon Dioxide
............. 0.677 1.161 0.551 Hydrogen Sulfide
........... 0.000 0.000 0.000 Nitrogen
...................... 3.323 3.626 1.742 Methane
...................... 58.464 36.543 47.240 Ethane
........................ 21.074 24.689 26.862 Propane
....................... 10.662 18.317 13.999 iso-Butane
................... 0.861 1.949 1.342 n-Butane
...................... 2.523 5.713 3.791 iso-Pentane
.................. 0.389 1.092 0.677 n-Pentane
.................... 0.599 1.684 1.035 Cyclopentane
............... 0.028 0.075 0.039 n-Hexane
..................... 0.196 0.657 0.384 Cyclohexane
................ 0.196 0.642 0.317 Other Hexanes
............. 0.147 0.492 0.287 Heptanes
..................... 0.338 1.321 0.744 

# • Methylcyclohexane
........ 0.129 0.493 0.247 2,2,4-Trimethylpentane
... 0.001 0.004 0.002 Benzene ...................... 0.085 0.257 0.113 Toluene
....................... 0.073 0.264 0.117 Ethylbenzene
............... 0.003 0.014 0.006 Xylenes
....................... 0.112 0.462 0.206 C8+ Heavies
................ 0.122 0.545 0.299 Totals
........................ 100.000 100.000 100.000 

# •

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % Cyclopentane 0.028 0.075 0.039 Cyclohexane 0.196 0.642 0.317



# • 2-Methylpentane 0.092 0.310 0.181 3-Methylpentane 0.054 0.182 0.106 n-Hexane 0.196 0.657 0.384 Methylcyclohexane 0.129 0.493 0.247 2.2,4-Tlimethylpentane 0.001 0.004 0.002 Benzene 0.085 0.257 0.113 Toluene 0.073 0.264 0.117 Ethylbenzene 0.003 0.014 0.006 m-Xylene 0.018 0.073 0.033 p-Xylene 0.076 0.313 0.139 o-Xylene 0.018 0.076 0.034

SPECIFIC GRAVIlY @ 60/60 F, calculated.................................................. . 0.8862 TOTALGPM (Ethane Inclusive)................•••.........•....•................•............•. 10,561 CALCULATED BTU 1REAL CF @ 14.73 PSIA, dry basis.................................. 1462,236 CALCULATED BTU 1REAL CF@ 14.73 PSIA, wetbasis.................................. 1437.527 AVERAGE MOLECULARWEIGHT........................................................... . 25.666 MOLAR MASS RATIO............................................................................. . 0.8862 RELATIVE DENSIlY ( G" Z (Air) 1Z ), calculated........................................ 0.8911 IDEALGROSS HEATING VALUE, BTU 1IDEALCF @ 14.696 PSIA................. . 1450.907 COMPRESSIBIUlYFACTOR (Z)............................................................ .. 0.99453
PROPANE GPM ................................................................................... .. 2.9297 BUTANEGPM ...................................................................................... . 1.0743 GASOUNE GPM (PENTANE AND HEAVIER) .......................................... . 0.9357
lHI I ,iii I ' ill PHY'H \1 « )" 1 .\"'T' I·' )H HYJ)IH )t ;](W**~"lJ** ' q III F ( , '\11" ,! 

# "I),(" I" ITHI 'I 

# • I': 1'111 '" \Tl R'I' C,**\~** 1'.1)\ 5Th\



# •

# •

29 Country Acrl.'s Rd, Riverton, WY 82501 Online, www.Precls\on-L1obs.com 

# PRECISION7s

Client: BISON ENGINEERING Sample 10: HIGH HAWK 4-9 Unique #: SampleTemperature: 59 DEG F Sampled By: TC County: DUNN E
.......i1:**Inf~r.clsion·L1obs.com** Toll Fre", Number. 1866) 985-0866
Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample: 10/11/2011 10/11/2011 

# • 25 PSI ONLINE

Components Mole % Weight % Liq.Vol. % Carbon Dioxide
............. 0.517 0.681 0.356 Hydrogen Sulfide
........... 0.000 0.000 0.000 Nitrogen
...................... 0.562 0.471 0.249 Methane
...................... 28.060 13.456 19.176 Ethane
........................ 34.433 30.949 37.122 Propane
....................... 25.191 33.204 27.977 iso-Butane
................... 2.180 3.787 2.875 n-Butane
...................... 6.332 11.001 8.047 iso-Pentane
.................. 0.795 1.714 1.172 n-Pentane
.................... 1.017 2.194 1.487 Cydopentane
............... 0.037 0.079 0.045 n·Hexane
..................... 0.146 0.375 0.242 Cyclohexane
................ 0.047 0.119 0.065 Other Hexanes
............. 0.291 0.749 0.482 

# • Heptanes
..................... 0.084 0.252 0.157 Methylcyclohexane
........ 0.025 0.073 0.040 2,2,4-Trimethylpentane
... 0.000 0.000 0.000 Benzene
...................... 0.Q18 0.043 0.021 Toluene
....................... 0.069 0.190 0.093 Ethylbenzene
............... 0.004 0.011 0.005 Xylenes
....................... Om5 0.049 0.024 C8+ Heavies
................ 0.177 0.605 0.366 Totals
........................ 100.000 100.000 100.000 

# •

# •

ADDITIONAL BETX DATA Components Mole % Weili,ht %**Li~.** Vol. %



# • Cydopentane 0.037 0.079 0.045 Cyclohexane 0.047 0.119 0.065 2-Methylpentane 0.183 0.471 0.303 3-Methylpentane 0.108 0.278 0.179 n-Hexane 0.146 0.375 0.242 Methylcyclohexane 0.025 0.073 0.040 2.2,4-Trimethylpentane 0.000 0.000 0.000 Benzene 0.018 0.043 0.021 Toluene 0.069 0.190 0.093 Elhylbenzene 0.004 0.011 0.005 m-Xylene 0.002 0.008 0.004 p-Xylene 0.010 0.033 0.016 o-Xylene 0.003 0.008 0.004

SPECIFIC GRAVlTY @ 60/60F, calculated.................................................. . 1.1551 TOTALGPM (Ethane Inclusive)................................................................. 19.847 CALCULATED BTU / REAL CF @ 14.73 PSIA. dry basis.................................. 1945.085 CALCULATED BTU / REAL CF @ 14.73 PSIA. wet basis................................. . 1911.926 AVERAGE MOLECULARWEIGHT........................................................... . 33.454 MOLAR MASS RATIO............................................................................. . 1.1551 RELATIVE DENSITY ( G x Z (Air) / Z ),calculated...................................... .. 1.1668 IDEALGROSS HEATING VALUE, BTU / IDEALCF @ 14.696 PSIA................ .. 1921.067 COMPRESSIBIliTYFACTOR (Z).............................................................. 0.98992
PROPANE GPM ................................................................................... .. 6.9222 BUTANEGPM ...................................................................................... . 2.7025 GASOliNE GPM (PENTANEAND HEAVlER) ........................................... 1.0377 

# •

•

# • PRECISION;?**~SIS**
Client: BISON ENGINEERING WILLIAMS Sample 10: NATHAN HALE 3-18 Unique#: Sample Temperature: 59 DEG F Sampled By: TC County: DUNN 29 Country Acres Rd, Riverton. WY 82501 Online: _w.Prec:I.,on·....b••com E·mall!**In~Pr** ..cl.lon·....bs.com Toll Free Numberl 1866) 985.(1866
Analysis Date: 10/11/2011 Date Sampled: 10/11/2011 Purpose: 

# • Sample Pressure: 15 PSI Type Sample: ONLINE

Coml:0nents Mole % We!iht % Liq.Vol. % Carbon Dioxide
............. 0.561 0.873 0.443 Hydrogen Sulfide
........... 0.000 0.000 0.000 Nitrogen
...................... 3.504 3.471 1.784 Methane
...................... 56.578 32.094 44.375 Ethane
........................ 15.797 16.795 19.545 Propane
....................... 11.394 17.765 14.522 iso-Butane
................... 1.536 3.156 2.325 n-Butane
...................... 5.735 11.786 8.364 iso-Pentane
.................. 1.045 2.666 1.768 n-Pentane
.................... 1.419 3.619 2.379 Cyclopentane
............... 0.102 0.252 0.139 n-Hexane
..................... 0.461 1.405 0.877 Cyclohexane
................ 0.304 0.903 0.478 Other Hexanes
............. 0.333 1.015 0.634 Heptanes
..................... 0.692 2.453 1.478 

# • Methylcyclohexane........ 0.242 0.842 0.451 2,2,4-Trimethylpentane
... 0.001 0.002 0.001 Benzene
...................... 0.192 0.530 0.248 Toluene
....................... 0.066 0.215 0.102 Ethylbenzene
............... 0.003 0.010 0.005 Xylenes
....................... 0.010 0.038 0.018 C8+ Heavies
................ 0.027 0.109 0.064 Totals
........................ 100.000 100.000 100.000 

# •

# ,e j 

# I 1 ADDITIONAL BETX DATA 

# I Components Mole % Weight % Liq. Vol. % 

# I Cyclopentane Cyclohexane

### ~ J 2-Methylpentane**~** 3-Methylpentane 

# I**~** n-Hexane Methylcyclohexane 

### J 2,2.4-Trimethylpentane Benzene Toluene Ethylbenzene 

### l

# • m-Xylene p-Xylene o-Xylene 0.102 0.252 0.139 0.304 0.903 0.478 0.210 0.639 0.399 0.123 0.376 0.235 0.461 1.405 0.877 0.242 0.842 0.451 0.001 0.002 0.001 0.192 0.530 0.248 0.066 0.215 0.102 0.003 0.010 0.005 0.002 0.006 0.003 0.007 0.026 0.012 0.002 0.006 0.003

SPECIFIC GRAVlTY @ 60/60F, calculated.................................................. . 0,9765 TOTALGPM (Ethane Inclusive)............................................................... .. 11.511 CALCULATED BTIJ / REAL CF @ 14.73 PSlA, dry basis.................................. 1602.761 CALCULATED BTIJ / REAL CF@ 14.73 PSIA, wet basis................................ .. 1575.593 AVERAGE MOLECULARWEIGHT........................................................... . 28.281 MOLARMASS RATIO............................................................................. . 0.9765 RELATIVE DENSITY( G x Z (Air) / Z ), calculated...................................... .. 0.9632 IDEALGROSS HEATINGVALUE, BTIJ / IDEAL CF@ 14.696 PSIA................. . 1568.143 COMPRESSIBIlJTYFACTOR (Z).............................................................. 0.99316
PROPANE GPM ................................................................................... .. 3.1309 BUTANEGPM ...................................................................................... . 2.3045 GASOlJNE GPM (PENTANE AND HEA VlER) ......................................... .. 1.6621 'dq,TIO" ,II (\I(II'd'l! I'!JU'\JI\\IIDlq"CI'Jllcl, il \("'II'CI'fkf'\I'F\H'··" lHI 1,IHr< 

# • I H- I'HY,J(\I ( (**i'~Ti** '<1' H)I( HY!)I,,)( '\I(BI .'" ,I) , 'Till l< ( • '\11', II**,IJ~')!** j',ITRL·l J<} rill ", HI H\i (. ,\'·1:,1)\ ,TRi



# •

# •

29 Country Acres Rd, Rlvtl'r1on. WY 82501 Online: www.Precl"lon·Loobs.c:om E·mail: Intof\'Preclsion·Loobs.eOm Toll Fre
.. N"mbtl'.: (866) 985.0866

Client: Sample 10: Unique#: Sample Temperature: Sampled By: County: BISON ENGINEERING WILLIAMS SKUNK CREEK 1-12

78 DEG F TC DUNN
Components Mole % Carbon Dioxide
............. Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... Ethane
........................ Propane
....................... iso-Butane
................... n·Butane
...................... iso·Pentane
.................. n-Pentane
.................... Cyclopentane
............... n-Hexane..................•.. Cyclohexane
................ Other Hexanes
............. Heptanes
..................... Methyicyclohexane
........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ Totals
........................ 0.596 0.000 3.717 46.514 22.053 16.952

1.718 5.657 0.829 1.021 0.070 0.263 0.077 0.061 0.231 0.034 0.000 0.015 0.044 0.004 0.018 0.125 100.000 Weight % 0.893 0.000 3.545 25.407 22.578 25.451

3.399 11.195 2.037 2.507 0.167 0.771 0.222 0.178 0.789 0.115 0.000 0.040 0.137 0.016 0.066 0.487 100.000 Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample:

Liq. Vol. % 0.454 0.000 1.828 35.242 26.359 20.872

2.512 7.971 1.355 1.654 0.092 0.483 0.118 0.112 0.477 0.062 0.000 0.019 0.065 0.008 0.032 0.287 100.000 10/11/2011 10/11/2011 

# • 30 PSI ONLINE



# •

# •

ADDITIONAL BETX DATA Components Mole % WeiJiht %**Li~.** Vol. % Cyclopentane 0.070 0.167 0.092 Cyclohexane 0.077 0.222 0.118 2-Methylpentane 0.038 0.112 0.070 3-Melhylpentane 0.023 0.066 0.041 n-Hexane 0.263 0.771 0.483 Melhylcyclohexane 0.034 0.115 0.062 

# • 2.2,4-Trimelhylpenlane 0.000 0.000 0.000 Benzene 0.Q15 0.040 0.019 Toluene 0.044 0.137 0.065 Elhylbenzene 0.004 0.016 0.008 m-Xylene 0.003 0.011 0.005 p-Xylene 0.012 0.045 0.021 o-Xylene 0.003 0.011 0.005

SPECIFIC GRAVITY @**~/~** F, calculated.................................................. . 1.0141 TOTAL GPM (Ethane Inclusive)................................................................. 13.943 CALCULATED BTU 

### I REAL CF @ 14.73 PSIA, drybasis.................................. 1663.548 CALCULATEDBTU 

### I REAL CF @ 14.73 PSIA, wet basis................................. . 1635.316 AVERAGE MOLECULARWEIGHT........................................................... . 29.370 MOLAR MASS RATIO............................................................................. . 1.0141 RELATIVE DENSITY ( G x Z (Air) I Z ).calculated...................................... .. 1.0215 IDEAL GROSS HEATINGVALUE. BID I IDEAL CF @ 14.696 PSIA................ .. 1647.712 COMPRESSIBILITYFACTOR (Z).............................................................. 0.99276
PROPANE GPM ................................................................................... .. 4.6583 BUTANEGPM .•..........•....•...•..........••.......•..........•..........••..•....•..........•... 2.3395 GASOLINE GPM (PENTANEAND HEAVIER) .......................................... . 1.0627 

# •



# •

# •

29 Country Acre5 Rd, Riverton, WY 82501 Online: _P,..clalon-Laba.com

# PRECISIO~ E-mail: Intofl.Preclalon-Laba.com Toll Free Numben (866) 985-0866

# ~SiS
Client: Sample 10: Unique#: SampleTemperature: Sampled By: County: BISON ENGINEERING WILLIAMS TAT 2-1

117 DEG F TC DUNN Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample: 10/11/2011 10/11/2011 

# • 17 PSI ONLINE

Components Mole % Carbon Dioxide
............. Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... Ethane
........................ Propane
....................... iso-Butane
................... n-Butane
...................... iso-Pentane
.................. n-Pentane
.................... Cyclopentane
............... n-Hexane
..................... Cyclohexane
................ Other Hexanes
............. Heptanes
..................... Methylcyclohexane
........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ Totals
........................ 0.644 0.000 1.573 39.023 23.624 20.193

2.557 7.945 1.185 1.596 0.101 0.369 0.172 0.417 0.393 0.099 0.001 0.031 0.034 0.002 0.007 0.035 100.000 We!iht% 0.870 0.000 1.352 19.208 21.796 27.321

4.559 14.169 2.623 3.532 0.217 0.975 0.445 1.101 1.209 0.299 0.002 0.075 0.097 0.007 0.021 0.121 100.000 Liq. Vol. % 0.462 0.000 0.727 27.788 26.538 23.368

3.514 10.521

1.820 2.430 0.125 0.637 0.246 0.720 0.762 0.168 0.001 0.037 0.048 0.004 0.011 0.074 100.000 

# •



# •

# I



# •

ADDITIONAL BETX DATA Components Mole % Wei/iht % 

### Li3' Vol. % Cyclopentane 0.101 0.217 0.125 Cyclohexane 0.172 0.445 0.246 2-Methylpentane 0.262 0.693 0.453 3-Methylpentane 0.154 0.408 0.267 n-Hexane 0.369 0.975 0.637 Methylcyclohexane 0.099 0.299 0.168 2,2,4-Trimethylpentane 0.001 0.002 0.001 Benzene 0.031 0.075 0.037 Toluene 0.034 0.097 0.048 Ethylbenzene 0.002 0.007 0.004 

# • m-Xylene 0.001 0.003 0.002 p-Xylene 0.004 0.014 0.007 o-Xylene 0.001 0.003 0.002

SPECIFIC GRAVITY@60/60F,calculated................................................. .. 1.1253 TOTALGPM (Ethane Inclusive)................................................................. 16.864 CALCULATED BTU / REAL CF @ 14.73 PSIA, drybasis.................................. 1874.169 CALCULATEDBTU / REAL CF @ 14.73 PSIA, wet basis................................ .. 1842.251 AVERAGE MOLECULARWEIGHT.......................................................... .. 32.591 MOLAR MASS RATIO............................................................................. . 1.1253 RELATIVE DENSITY ( G x Z (Air) / Z ), calculated........................................ 1.1360 IDEALGROSS HEATING VALUE, BTU / IDEAL CF @ 14.696 PSIA................ .. 1852.257 COMPRESSIBIUTYFACTOR (Z).............................................................. 0.99058
PROPANE GPM ................................................................................... .. 5.5490 BUTANEGPM ...................................................................................... . 3.3329 GASOUNE GPM (PENTANEAND HEAVIER) .......................................... . 1.6803 

# •



# •

# •

29 Country Acres Rd. Riverton. WY 82501 Online. _w.Precl.'olPl-Lab••com 

# PRECISION2 E.....II' ' ..'o(!1Precl.ion·...b••com Toll Free N ..m .....' (861i) 985-0866

# ~SfS
Client: Sample 10: Unique#: Sample Temperature: Sampled By: County: BISON ENGINEERING WILLIAMS WELL 32-29

66 DEG F TC DUNN Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample: 10/11/2011 10/11/2011 

# • 20 PSI ONLINE

Components Mole % Carbon Dioxide.•........... Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... Ethane
........................ Propane
....................... iso-Butane
................... n-Butane
...................... iso·Pentane
.................. n-Pentane
.................... Cydopentane
............... n-Hexane
..................... Cydohexane
................ Other Hexanes
............. Heptanes
..................... Methylcyclohexane
........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ Totals
........................ 0.512 0.000 1.570 39.457 27.369 20.271

2.013 5.884 0.765 1.021 0.054 0.193 0.066 0.261 0.240 0.081 0.000 0.015 0.073 0.004 0.D15 0.136 100.000 Weight % 0.724 0.000 1.414 20.353 26.461 28.740

3.763 10.995

1.776 2.368 0.123 0.536 0.180 0.724 0.773 0.254 0.000 0.038 0.216 0.014 0.050 0.498 100.000 Liq. Vol. ./. 0.372 0.000 0.735 28.475 31.158 23.773

2.805 7.896 1.192 1.575 0.069 0.339 0.096 0,457 0.471 0.138 0.000 0.018 0.104 0.007 0.024 0.296 100.000 

# •



# •

# •

ADDITIONAL BETX DATA Components Mole % Wei

### 2 ht % Liq. Vol. % Cyclopentane 0.054 0.123 0.069 Cyclohexane 0.066 0.180 0.096



# • 2-Methylpentane 0.164 0.455 0.288 3-Methylpentane 0.097 0.268 0.169 n-Hexane 0.193 0.536 0.339 Methylcyclohexane 0.081 0.254 0.138 2,2,4-Trimethylpentane 0.000 0.000 0.000 Benzene 0.015 0.038 0.018 Toluene 0.073 0.216 0.104 Ethylbenzene 0.004 0.014 0.007 m-Xylene 0.002 0.008 0.004 p-Xylene 0.010 0.034 0.016 o-Xylene 0.002 0.008 0.004

SPECIFIC GRAVITY @ 60/60F, calculated................................................. .. 1.0738 TOTALGPM (Ethane Inclusive)................................................................. 16,499 CALCULATED BTU / REALCF @ 14.73 PSIA. drybasis................................ .. 1796.792 CALCULATEDBTU / REALCF @ 14.73 PSIA, wet basis.................................. 1766.229 AVERAGE MOLECULARWEIGHT........................................................... . 31.101 MOLAR MASS RATIO............................................................................. . 1,0738 RELATIVE DENSITY ( G x Z (Ail) / Z ), calculated...................................... .. 1.0830 IDEALGROSS HEATINGVALUE, BTU / IDEAL CF @ 14.696 PSIA................. . 1777.412 COMPRESSIBILITY FACTOR (Z).............................................................. 0.99149
PROPANE GPM ................................................................................... .. 5.5702 BUTANEGPM ...................................................................................... . 2.5073 GASOLINE GPM (PENTANE AND HEAVIER) ......................................... .. 1.1204

0] !I{), '.II ("I(IIITH PI Hi()j(\IID{ "],(,I'H\SI( ·\i "''',J\"\I>JI'.' '.1' :llI T \ill 1 . 

# •



# •

# •

29 C:ountry Acre. Rd, Riverton, WY 825D1 Onlln.: _.Pr.clslon·Labs.com 

# PRECISIONZ E_all. IntoC!ll'r_lsion.Labs.c:om Toll Free Numbe.. 18(6) 985.0866

# ~SIS
Client: Sample 10: Unique #: Sample Temperature: Sampled By: County: BISON ENGINEERING WILLIAMS WOLF 27-34

60 DEG F TC DUNN Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample: 10/11/2011 10/11/2011 

# • 30 PSI ONLINE

Components Mole % Carbon Dioxide
............. Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... Ethane
........................ Propane.....................•. iso-Butane
................... n-Butane
...................... iso-Pentane
.................. n-Pentane
.................... Cyclopentane
............... n-Hexane
..................... Cyclohexane
................ Other Hexanes
............. Heptanes
..................... Methylcyclohexane
........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ Totals
........................ 0.514 0.000 2.455 55.961 21.138 11.397

1.184 3.503 0.833 1.363 0.097 0.357 0.150 0.456 0.400 0.082 0.000 0.030 0.032 0.002 0.007 0.039 100.000 Weight % 0.836 0.000 2.541 33.170 23.484 18.569 2.543 7.523 2.219 3.634 0.250 1.138 0.467 1.453 1.481 0.299 0.000 0.085 0.110 0.006 0.026 0.166 100.000 Liq. Vol. % 0.406 0.000 1.250 43.916 26.169 14.535

1.794 5.113 1.409 2.287 0.132 0.680 0.236 0.868 

# • 0.854 0.153 0.000 0.038 0.050 0.003 0.012 0.093 100.000


# •

### 1 

# I

# •

ADDITIONAL BETX DATA Components Mole %**Wei~ht** % Liq. Vol. % Cyclopentane 0.097 0.250 0.132 Cyclohexane 0.150 0.467 0.236 2-Methylpentane 0.287 0.914 0.547 3-Methylpentane 0.169 0.538 0.322 n-Hexane 0.357 1.138 0.680 Methylcyclohexane 0.082 0.299 0.153 2.2,4-Trimethylpentane 0.000 0.000 0.000 Benzene 0.030 0.085 0.038 Toluene 0.032 0.110 0.050 Ethylbenzene 0.002 0.006 0.003 m-Xylene 0.001 0.004 0.002 

# ,e p-Xylene 0.005 0.018 0.008 o-Xylene 0.001 0.004 0.002

SPECIFIC GRAVITY @ 60/60 F, calculated.................................................. . 0.9345 TOTALGPM (Ethane Inclusive)................................................................. 11.726 CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis.................................. 1558.098 CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis................................. . 1531.712 AVERAGE MOLECULAR WEIGHT........................................................... . 27.065 MOLAR MASS RATIO............................................................................. . 0.9345 RELATIVE DENSITY ( G x Z (Air) / Z ). calculated....................................... . 0.9403 IDEALGROSS HEATING VALUE. BTU / IDEALCF @ 14.6%PSIA................. . 1544.831 COMPRESSIBIUTYFACTOR (Z).............................................................. 0.99377
PROPANE GPM ................................................................................... .. 3.1318 BUTANEGPM ...................................................................................... . 1.4882 GASOUNE GPM (PENTANE AND HEAVIER) ......................................... .. 1.4675 

# •



# •

# • ATTACHMENT F: ENGINE MANUFACTURER'S SPECS



# •

•

Dakota-3 E&P Company. LLC. NSR Synthetic MinorApplication WEP211324 

# •

# This section ofthe document has been redacted because it contains copyrighted information. The redacted information canbe viewed from the hard copy ofthe docket, which is available at the EPA Region 8 Office upon request.

# • RENTAL 

# C.ATERPILLARe

Arrangement shown with optional trailer 

# • FEATURES EMISSIONS • EPA Tier 3 and CARB Emissions Certified for

non-road mobile applications at all 60 Hz and 50 Hz ratings CAT C9 ATAAC DIESEL ENGINE • Utilizes ACERT" Technology • Reliable, rugged, durable design • Field-proven in multiple applications

worldwide • Four-stroke-cycle diesel engine combines

durabilitywith minimum weight while providing dependability and economy • 50/60 Hz convertibility CAT SR4B GENERATOR • Designed to match performance and output

characteristics of diesel engines • Permanent magnet excitation 

# • • Segregated AC/DC, lowvoltage accessory box provides single pointaccess to accessory connections ENCLOSURE • Made with 12-gauge steel • Single point lifting eye • Sound attenuated • Convenient hand holds and steps for safe

operation • Two coat polyester powder-coated finish 

# XQ230 

# SOUND ATTENUATED DUAL VOLTAGE 50/60 Hz

ENVIRONMENTALLY FRIENDLY DESIGN • Sound attenuatedfor low noise operation • OSHA compliant safe design • 110% spill containmentforcoolant and oil • Ul142 certified dual wall fuel tank MULn·VOLTAGE DISTRIBUTION PANEL • Simultaneous dual voltage • load door safety switch • Rust-free hinges on all doors • Adequate space for line and plug connection

without interference • Remote start and stopcontacts SINGLE·SOURCE SUPPUER • Complete systems designed at Caterpillar

ISO 9001:2000 certified facilities • CertHied PrototypeTested with torsional

analysis**WORLD~DEPRODUCTSUPPORT** • Worldwide parts availabilitythrough the

Caterpillar dealer network • With over 1,875 dealer outlets operating in

200 countries, you're never far from the Caterpillar partyou need. • 99.7% of parts orders filled within 48 hours.

The best product support record inthe industry. • Caterpillar dealer servicetechnicians are

trained to service every aspect ofyour electric power generation system.

LEHE5329-03 

# • 

# I

# • RENTAL 

# C.TERPILLARe



# • STANDARD FEATURES Air Inlet System Air cleaner, dual element Turbocharger Charging System Battery charger Heavy duty charging alternator Control Panel Generator controls and monitoring Fuel tank monitoring Engine controls and monitoring Digital displays Cooling System Fan and belt guards Base mounted radiator Airto air aftercooling Distribution Panel Lockable doors Load door safety switch, (trips breaker

upon dooropening) Individual bus barconnections Circuit breakerwith 24 VDC shunttrip Flemote start/stopcontacts Shorepower connections Enclosure Sound attenuated 12-gauge steel Lockable doors Separate vented battery compartment Single point lifting Exterior oil and waterdrainswith Interiorvalves Hidden exteriorfuel drain Hand holds and steps Powder coatedfinish Fuel System Primary fuel flltar/Water separator UL142 dual wall fuel tank 1667 L(440 gan Radiator-mounted fuel cooler Generator

i Brushless, permanent magnet Coastal corrosion protection Shock mountedVR6 voltage regulator Space heater UL approved Simultaneousthree-phase 480/277 end

240/139 voltage Mounting System Generator softmountedto base Base contains Integral fuel tank Sklddable structural steel design 110% oil and coolant spill containment Starting System Electric starting motor Battery setwith disconnect switch Jacket water heater with thermostat,

shut-offvalves 

### FACTORY INSTALLED STANDARD AND OPTIONAL EaUIPMENT OPTIONAL FEATURES Trailer Full frame support Indapendenttandemaxle trailerframe

with tongue Electric actuatad hydraulic brakes

with rechargeable battery backup breakaway system. Overeenter mechanical parking brake Full length fenders Non-skid surface on steps Heavy duty sefety chains and

grab hooks Reinforced 4640 kg (10,000 Ibl top

wind dropJack

lEHE5329-03 2 

# •

•

# • RENTAL**C~TERPILLAR·** SPECIFICATIONS CAT SR4B GENERATOR Frame size ....................••.•.••.•....•..........449 Type..........................Permanent magnet brushless Construction••.........•.....•Single bearing, close coupled Three-phase ......................... 12 lead reconnectable Insulation ••...••..Class Hwith coastal insulation protection IP rating ................................................22 Alignment....••.•.•...•.........•••...•..•...•..Pilot shaft Voltage regulator ••..... 3-phase sensingwith Volts-per-Hertz Voltage regulation•......, ........... :!: %% steady state/:!: %% no loadtofull load TIF ••••.••..••...••...•.....•......•..•••...••lessthan 50 THO .........................................lessthan 5% 

# •

TECHNICAL DATA



# • ENGINE C9 ATAAC, 4-stroke·cycle watercooled diesel Bore
- mm (In) ...............................,•. 112 \4.411 Stroke
- mm (in) ..•.............•....•••.•.....• 149 (5.87) Displacement- l (cu inl............... , ...........8.8 (6371 Compression ratio ................................... 16.1:1 Aspiration..•..•.........•..Turbocharged AA charge cooled Engine control ..••.••..•.•.......•.•..•..•.••..ADEM1M A4 

### CAT CONTROL PANEL
- EMCP 3.2 24 Volt DC Control NEMA 1, 1P22 enclosure Lockable hinged door Enclosure mounted Singlelocation customerconnectorpoint 16 light alarm modulewith alarmhorn Electric fuel level gauge ConsultyourCaterpillar dealerfor availablevoltages.

X0230 PowerRating

60Hz 50Hz ekW kVA Standby TMlRIf. Prime TMlFW. 230 DM8502 210 DM8512 215 DMBS04 Engine and ContainerInformation

Engine model Containerdimensions C9 seechartonJ)8ge 6 ShippingWeIght IDry)

Unit withtrailer kg ObI 6210 113,690) Unit withouttrailer Maximum fuel CapacityWeight kg ObI 4980 (10,980)

Unit with traiier kg (Ibl 7606 (16,550) Unit withouttrailer kg UbI 6278 (13,840) EngineLubricating

### on Capacity Engine CoolantCapacitywith Radiator fuelTank Capacity L(gal) L(gal) Ligal) 40 (10.65) 36 (9.61 1616 (4001 fuelConsumption L/hr (gaVt'!rl 69.2 (18.3) 64.7 (17.11 Fuel Consumption 176% Prime) L/hr (gaVt'!r) 60.6 (13.4) RunnIng time @ 75% PrIme SoundLevel hours 28

Standby dBIA) 74.72 No load @ 7 m (23 ftl dBlA) 70.20 Prime dBIA) 73.49 Ambient Capability Deg C(Deg Fl 43 (109.41

LEHE5329-03 3 

# •

# • RENTAL**C~TERPILLAR·**
RATING DEFINITIONS AND CONDITIONS Meets or Exceeds International Specifications: • NEMA MGl-32.IEC 60034, eSA. 9BJ37/EEC, 72/23/EEC,

UL 50B, UL142, IS03046/1, IS08528. 89/336/EEC Standby
- Output available with varying load for the duration ofthe interruption ofthe normal source power. Standby power In accordance with IS08528. Fuel stop power in accordancewith IS03046/1, AS2789. DIN6271, and 8S5614. Prime
- Output available with varying load for an unlimited time. Prime power in accordancewith IS08528. 10% overload powerin accordance with IS0304611, AS2789, DIN6271. and 8S5514 available on request. Ratings are based on SAE J1349 standard conditions. These ratings also apply at IS03046/1, DIN6271, and 8S5514 standard conditions. Fuel fates are based on fuel oil of 35" API [@ 16" C 160" F)J gravityhaving an LHV of42 780 kJ/kg 118,390 Btullb) when used at 29° C 185"F) and weighing 838.9 g/Iiter (7.001 Ib/U.S. gel). Additional ratings may beavailable for specific customer requirements. ConsultyourCaterpillar representativefor details. 

# •

•

LEHE5329-03 4 

# •

# • RENTAL 

# C..lTERPILLARDISTRIBUTION PANEL 

# CJ\TERPILLAR'


# •

• ® Wiring Descriptions 1. 800 amp main breaker 240V with 24V shunttrip 2. 400 amp main 480V with 24V shunttrip 3. 50 amp 240V branch breaker 4. 20 amp 240V branch breaker 5. 20 amp 120V branch breaker 6. 15 amp 120V branch breaker 7. 50 amp240V twistlock receptacle 8. 20 amp 240V twistlock receptacle 9. 20 amp 120Vtwistlock receptacle (2x) 10. 20 amp 120V ground fault interrupter, (2x) 11. 15 amp 120V groundfault interrupter, duplex receptacle (2x) 12. 30 amp 120V battery charger/generator space heater receptacle 13.30amp 120V JWH receptacle 14. Remote start/stop contacts 15. 12.7 mm (*-) ground stud 16. Dual voltage load connection bus board [6.35 mm 

### x 101.6 mm 

### x 101.6 mm (y..- x 4" x 4-) bus bars)



# •

lEHES329-03 5 

# •

# • RENTAL 

# C.TERPILLARe



### CONTAINER DIMENSIONS- TOP VIEW**2n.8(IO.74J+--~.** 

# •
1----------6239.7[:m.66 )----**~--~** 

### CONTAINER DIMENSIONS - RIGHT SIDE VIEW

.........­ 2.251
Overall Dimensions Package WithTrailer Length 4597.4mm 181in 6248.3mm 246 in Width 1498.6mm 59 In 2540.0mm 100 in Height 2387.6mm 94 In 2882.8 mm 113.5 In 

# •

LEHE5329-03 6 

# •

# • ATTACHMENT G: EMISSION CONTROL DEVICE MANUFACTURER'S SPECS


# •

•

Dakota-3 E&PCompany. LLC. NSR Synthetic MinorApplication WEP211324 

# •

# • C""N CIMARRON ENERGY INC. 

# EMISSION CONTROL DEVICES (ECD)


# •

Cimarron Energy Tank voe Emission Control Devices are enclosed flares that are low maintenance with safe reliable operation, userfriendly, easy to install, and highly efficient. These units are engineered to capture and combustvae emissions from the Oil/Condensate Production Tanks with clean efficient destruction. Cimarron EeDs have been independentlytested and certified to exceed the strict EPA requirements with a 99% destruction rate. Specifications on the next page. Auto Ignition systems also available
. 

# •

Home Olliee: 1-{580,33e·S4116 FAX 1-(580) 338-0885 P.O. BOll I'OS, GlI)'lTlon. Okillhoma 731M2 Admlnistrativ.

### om".; 1-(405) 828·7373 FAX t·(405) 926·73110 P.O. 80" 722110, Norman. OI\laho_ 73070 

# •

# • 

# • }

# .

.. .-j 

# \


# o mil.



### ""-.0,**~** ElQDI\ Ji/nliO 

# + 48' DIA x 302 5/fr' H9GHT, 88 ORIFICES EMISSION CDNTROl DEVICE 

### '* >98%TVOC ORE, CERTJ.flED USEPA 40 a=R 60, APPENDIXA. SClURCE EMMISIONSTEST METHODS REfERENC.E). MEETS AllEPA 8t COPHE REGULATIONS. • DESTROYS OIl1CONIJENSAlE PRODUCTION TANKVAfIORS 

### WINO VISIBLE RAME.

.. EXCB.LfNTOPACITYAND 5MOKB.ESS DPERAllON•

.. REUABI.E AND OJSTOMIZABLEIGNITION•

.. 'VERYI.J:INCAPITAlAND OPERATING COST•

.. fAS(TO OPERAlEAND MAINTAIN. " WD.L DfSTROY UPTO 150 MCFD @ lDol/inZ

1It:lD5GN1

OI!I:: 8

I'H'_I II.

, ...... >ICH8X.lE(}f**~** -,-1IrSC

__**---:-=:c:-::=~=~--** 

### -.IQ!'II**_~~..:** 

### I**~a:'** 

### I :
..**,~...** 

### .......__**~** 

### ..... 

# CIMARRON "-:floe 

# •

# • ATTACHMENT H: PROCESS FLOW DIAGRAM OF FACILITY


# •

•

Dakota-3 E&P Company, LLC. NSR Synthetic Minor Application WEP211324 

# •

# •

--------- 

# • • 

# •
TYPICALMANDAREE AREA TWOWELLPAD FACILITYPLOTPLAN Dakota-3E&PCompany, LLC FBIR, NorthDakota Wa
.. PIpeline 011 PIpeline NOTTO SCALE 

# 8**GaoMoter~.** _______ ..II TIlllkV
...tBne Gao ........ I I



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# , I I I I I o I

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## -"'.-"","+: Gu_ 

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# .. ... ' I Utility "1t::...t_1I>1 Flare --I vam. 

# , -. I

Legend Derma !!!!!!!!!!!! WaterLine CIucIe Line FIo",1ino: Buried R..-,.:leLI"", OUSalooLine TankVaporLillo I'1JII'OdOULIlle**~""".r"'",.~'\"""'Il'""** ....,-_,,,,,,,,,,,..ot....**_",,~r·,,~,,,,,,,,,,·,,,,,,,,,,,---~,,,,_._._.,~~_fII'~,4!** "m:<JI,:V_.1_1W**"'~It ,4:a;;!t'~'~,**  paw ,Nt'"**~~** 1:Il!I2l4, Nri"ii_"M'I'llW"l'iC"!li\III**ik~_,' .1t%i!lJ\I!!lJ!M~~~'''_''I:l,''',**  __ ..''h'''_'

__ ''''

___________________________

# • ATTACHMENT I: PRODUCTION DECLINE CURVE CALCULATIONS


# •

•

Dakota-3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324 

# •

# • ATTACHMENT

# J: DIESEL TANK EPA TANKS 4.09D EMISSIONS SUMMARY



# •

•

Dakota·3 E&P Company, LLC. NSR Synthetic MinorApplication WEP211324 

# •__ 

# • • • TANKS 4.0 Report Page I of6

IdentifIcation User Identification: City: State: Company: Type ofTank: Description: Tank Dimensions Shell Length (ft): Diameter (ft): Volume (gallons): Turnovers: Net Throughput(gal/yr): Is Tank Heated (yIn): Is Tank Underground (yIn): Paint Characteristics Shell ColorlShade: Shell Condition Breather Vent Settings Vacuum Settings (psig): Pressure Settings (psig) 

### TANKS 4.0.9d 

### Emissions Report - Detail Format Tank Indentiflcatlon and Physical Characteristics
1000 gallon diesel tank Williston North Dakota Williams E&P, LLC Horizontal Tank 1,000 gallon diesel tank to fuel onsite diesel generators. Tank throughput is based on engine fuel consumption.
10.00 4.16 1,000.00 2,244.31 2,244,312.00 N N Gray/Medium Good
-0.03 0.03 Meterological Data used in Emissions calculations; Bismarck. North Dakota (Avg Atmospheric Pressure == 13.86 psia) 

# •**~~,** • .$**~,** w,t$.**!!'!II'!\I,_~W '~f.** **4'~,** 1*.**~ ~!iA@i1itWW%t~_!)(4** **1~(4'l''''li:N.~ Ri'II,..t""~~~~\iI**  "'I'i"f_' filp·/lr·\Prnor!'lrr!**Pilp~\T!'Inlr~A.nQrl\~IIrr!rr!!'Irvrli~nl!'lv** htrr! 9129/2011

# • 

# • • TANKS 4.0 

### Report Page 2 of6

1000 gallon diesel tank - Horizontal Tank Williston, North Dakota 

### TANKS 4.0.9d Emissions Report - Detail Format Liquid Contents of Storage Tank

Mixture/Component Distilale fuel oil no, 2 Month All Daily Liquid Sur!, Temperature (deg F) Avg, Min, Max, SO,18 39,12 60,64 Liquid Bulk Temp (degF) 44.68 Vapor Pressure (psia) Avg. Min. Max, 0.0045 0.0031 0.0061 vapor Mol Weight 130,0000 Liquid Mass Fracl. Vapor Mass Fracl. Mol. Weighl 188.00 BaSIS lor Vapor Pressure Calculallons Opllon 1: VP50 • ,0045 VP60. ,0065

filp.·//r·\PrnM:lm Filp.r;:\T:lnh4()QrI\r;:n.mllrvrlir;:nlllV htm 9/29/2011

# • • 

# • • TANKS 4.0 Report Page 3 of6


### TANKS 4.0.9d Emissions Report· Detail Format Detail Calculations (AP-42) 1000 gallon diesel tank - Horizontal Tank Williston, North Dakota

Annual Emission CalcaulaHons Slanding losses (Ib):

Vapor SpaCAII Volume (eu fI): Vapor DensUy lIb/eu H): Vapor Space E_nsion Facior: Venled Vapor Saturation Factor: Tank Vapor Space Volume:

Vapor Space Volume (eu II): Tank Diameter (H): Effective Diameter (H): Vapor SpaCAII Oulage (II): TanI< Sheillangih (ft): vapor Densily

Vapor Dens!!}' (Ib/eu H): Vapor MolecularWeight (Ibnb-mole): Vapor Pressure al Daily Average liqUid

Surface Temperature (psia): Dally Avg. liquid Surlace Temp. (deg. R): Dally Average Ambient Temp. (deg. F): Ideal Gas Constanl R

(psla euff I (Ib·mol-deg R)): liquid BulkTemperelure (deg. Tanl< Painl Solar AbsorptanCAII DallyTotal Soiar Insulallon

Factor (BlulSQft day) Vapor Space Expansion Faclor

Vapor Space Expansion Faclor: DaHy VaporTemperature Range (deg. A): Daily Vapor Pressure Range (psla): Brealher Vent Press. Setllng Range(psia): Vapor Pressure al Dally Average liquid

Surface Temperature (psla): Vapor Pressure at Dally MInimum liquid

SurfaCAII Temperature (psia): Vapor Pressura al Dally Maximum liQuid

Surface Temperature (psia): Dally Avg. liquid SurfaCAII Temp. (deg R): Dally Min. Liquid Surface Temp. (deg R): Dally Max. liquid SurfaCAII Temp. (deg A): Dally Ambient Temp. Range (deg. R): Vented Vapor Saluration Faclor

Vented Vapor Saluralion Facto,· Vapor Pressure al Dally Average Liquid:

Surfaca Temperature (psia): Vapor Space Outage (If): Working losses (Ib):

Vapor Molecular Weight (lbnb-mole): Vapor Pressure al Daily Average lIquid

SuriaCAII Temperature (psia): Annual Net Throughput (gallyr.): 0.2654 1l6.57t9 0.0001 0.0780 0.9995 1l6.5719 4.1600 7.2797 2.0800 10.0000 0.0001 130.0000

0.0045 509.8466 41.5958

10.731 504.3458

0.6800 1.276.2450 0.0780 41.83n 0.0036 0.0600 0.0045 0.0031 0.0067 509.8466 499.3872 520.3060 24.3583 0.9995 0.0045 2.0600 5.6720 130.0000

0.0045 2,244,312.0000
9/29/2011 

### file:/IC:\Prot!ram Files\Tanks409d\summarvdisolav.htm

# • 

# • • Page 40f6 TANKS 4.0 Report

Annual Turnovers: 2,244.3120 Turnover Factor: 0,1800 Tank Diameter (ft): Working lOSS Product Factor' Tolal Losses (Ib)' 5.9375



### 9/29/201 I**file~/lr'\PrnpT~m Files\T~nks409n\sl.,m~rvnisnl~v.htm** 

# • • • TANKS 4.0 Report Page 5 of6


### TANKS 4.0.9d Emissions Report - Detail Format Individual Tank Emission Totals Emissions Report for: Annual 1000 gallon diesel tank - Horizontal Tank Williston, North Dakota 

### I II Losses(lbs) 

### I IComponents 

## II Working Lossil Breathing Lossil Total Emissionsl IDistiliate fuel oil no. 2 

## II 5.6711 0.2711 5.941 

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