# •

APPLICATION FORANN-,.::;;.;;;.-.;;;...;;..---::...;;.l PSDITITLE V SYNTHETIC MINOR AIR QUALITY PERMIT WOLF CHIEF 27-34H AD OIL 

# & GAS FA_&AoI&.

Preparedby: 

## Bison Engineering, Inc. 

## 1400 11th Helena, 

## (406) 

# '"""

-- Deeemtier 29, 2011

- x, 

# -­ 

# -­ - -



# -

# •**~ ~OW~ij**  DAKOTA-3 E&P COMPANY, LLC 

# uU 

# CEC 29 

# 2011

# ~. a subsidiary orWilliams 1001 17" Street, Suite 1200 Denver, CO 80202 

# 8P-AR 3031527·3900 December 29, 2011

Ms. Kathleen Paser Duplicate submittal provided via e-mail to: MinorNSRPennittingCoordinator rSairpennitting@epa.gov 

# • U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129
Re: Synthetic Minor Source Pennit Application for the WolfChief27-34H Pad
DearMs. Paser: Dakota-3 E&P Company, LLC (Dakota-3) a subsidiary ofWilliams is submitting this Synthetic Minor Source Pennia Application for the Wolf Chief 27-34H 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 JoDeIl.Mizoue@Williams.com
. Sincerely, 

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

# •

# Jt!um~E StaffEnvironmental Specialist Attachment
cc: File Joe GilliesJr. Environmental Director, Environmental Division, 204 W. Main, New Town, ND 58763-9404 Tex Hall, Chainllan Three Affiliated Tribes, 404 Frontage Road, New Town, ND 58763-9404 (letter Only) 

## I 

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# •

# •

• UNITED STATES ENVIRONMENTAL PROTECTION AGENCY Region 8 AirProgram FEDERALMINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

## 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 and Budget. The following is a check listofthe type ofinfonnation 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 providing the information requested may help expedite the process. Use ofapplication forms for this program is currentlyunder Office ofManagement and Budgetreview and these informationrequest forms will be replaced/updated after that review is completed. Please suhmitinformationto following two entities: Minor NSRPermittingCoordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129 The Tribal Environmental Contact for the specific reservation: Ifyou needassistance in identifying the appropriate Tribal Environmental Contact and address, pleasecontactthe EPA Region 8 Tribal 

### Air Coordinator: Alexis North, EPARegion 8 Tribal 

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

### A

# . GENERALFACIliTY INFORMATION 

# • 1. (a) Company Name Dakota-3 E&P Company, LLC (b) OperatorName Dakota-3 

### E&P Company, LLC 2. Facility Name WolfChief27-34HPad

3. Type ofOperation Oil and Gas Production 4. Portable Source? 

# o Yes 

## I2J No 5. Temporary Source? 

## 0 Yes 

## I2J No 6. NAICS Code .7. SIC Code 213111 I 1311 8. Physical Address: 1001 17th Street, Suite 1200 Denver, CO 80202 9. Reservation* FBIR 10. County* Dunn lla. Latitude* 47.7011222 11b. Longitude* -102.5704266 12a. Quarter Quarter Section* NENW 12b. Section* 27 12c. Township* 12d. Range* Tl49N 

## I R93W 

# •

# • B. PREVIOUS PERMIT ACTIONS (Provide information in this format for each permit that has been issued to this facility. Provide as an attachment ifadditional space is necessary) This section ofthepermit application is not applicable. This application is for a new facility for which no previouspermit actions have been taken. Facility Name on the Permit 

### N/A Permit Number (xx-xxx-xxxxx-xxxx.xx) 

### N/A 

# I Date ofthe Permit Action 

### N/A 

# •

•

•

# • C. 

### CONTACT INFORMATION



# •

• Company Contact: loDell Mizoue Title: StaffEnvironmental Specialist Mailing Address: 1001 17th 

### Street, Suite 1200 Denver, CO 80202 Email Address: JoDell.Mizoue@Williams.com Telephone Number: (303) 606-4056 , Facsimile Number: (303) 692-8285**~-** I 

### Operator Contact (ifdifferent from company contact): Same as above Title Mailing Address Email Address Telephone Number Facsimile Number FaciUty Contact: Same as above Title Mailing Address Email Address Telephone Number Facsimile Number Compliance Contact: Same as above Title Mailing Address Email Address Telephone Number Facsimile Number



# •

# • D. ATTACHMENTS Include all ofthefollowing information 

### (see the attached instructions) ../ FORM SYNMIN

- 

### New Source Review Synthetic Minor Limit Request Form, ifsynthetic minor limits are being requested
. ../ Narrative description ofthe proposed productionprocesses. This description should follow the flow of the process flow diagramto be submitted with this application
. ../ Process flow chart identifying all proposed processing, combustion, handling, storage, and emission control equipment. ../ A list and descriptions ofall proposed emission units and air pollution-generating activities
. ../ Type and quantity offuels, including sulfur content offuels, proposed to be used on a daily, annual and maximum hourly basis. ../ Type and quantity ofraw materials used or final product producedproposed to be used 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. ../ Alist and description ofall proposed emission controls, control efficiencies, emission limits, and monitoring for each emission unit and air pollution generating activity
. ../ Criteria Pollutant Emissions

- 

### Estimates ofCurrent Actual Emissions, Current Allowable Emissions, PostChange Uncontrolled Emissions, and Post-Change Allowable Emissions for the following airpollutants: particulate matter, PMIO, 

### PM 2•

S , 

### sulfur oxides (SOx), nitrogen oxides (NUx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead compounds, fluorides (gaseous and particulate), sulfuric acid mist (H2

### S04), 

### hydrogen sulfide (H2

### S), total reduced sulfur (TRS) and reduced sulfur compounds, including all calculations for the estimates
. ../ These estimates are to be made for each emission unit, emission generating activity, and the project/facility in total. ../ Modeling - Air Quality Impact Analysis (AQIA) ../ ESA (Endangered Species Act) ../ NHPA (National Historic Preservation Act) 

# •

•



# •

# • 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 PM1• PM u

SOx 

# • NOx CO VOC

Pb Fluorides

8 2SO
..

8 2S TRS RSC 

### Potential Emissions (tpy) 0.49 0.49 0.49 0.14 30.95 60.63 1247.50 Negligible Negligible Negligible Negligible Negligible Negligible Proposed Allowable Emissions (tpy) 

### 0.60 0.60 0.60 0.14 33.34 73.65 49.55 Negligible Negligible Negligible Negligible Negligible Negligible PM

- Particulate Matter PM JO - Particulate Matter less than 10 microns in size PM2.5

- Particulate Matter less than 2.5 microns in size SOx

- Sulfur Oxides NOx

- Nitrogen Oxides CO

- Carbon Monoxide VOC

- Volatile Organic Compound Pb

- Lead and lead compounds Fluorides

- Gaseous and particulates H2S04 - 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 3020): (a) Coal cleaning plants (with thermal dryers); (b) Kraft pulp mitis; (c) Portlandcementplants; (d) Primaryzinc smelters; (e) Iron and steel mills; (f) Primary aluminum ore reduction plants; (g) Primary copper smelters; 

# • (h) Municipal incinerators capable ofcharging morethan 250 tons ofrefuseper day; (i) Hydrofluoric, sulfuric, or nitric acid plants; (j) Petroleumrefineries; (k) Lime plants; (I) Phosphaterock processingplants; (m) Coke oven batteries; (n) Sulfur recoveryplants; (0) Carbon black plants (furnace process); (P) Primary lead smelters; (q) Fuel conversion plants; (r) Sintering plants; (s) Secondary metal production plants; (t) Chemical processplants (u) Fossil-fuel boilers (or combination thereof) totaling more than 250 million British thermal units perhour heat input; (v) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels; (w) Taconite ore processing plants; (x) Glass fiber processingplants; (y) Charcoal production plants; (z) Fossil fuel-fired steam electric plants ofmore that 250 million British thermal unitsperhour heat input, and (aa) Any other stationary source categorywhich, as of August 7, 1980, is being regulated under section III or 112 ofthe Act.



# •

# • 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 (tpyl PM 

## N/A N/A N/A N/A PM10 

## N/A N/A N/A N/A PM 20S 

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

SOx 

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

## 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 NJA N/A NH3 

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

## N/A N/A N/A N/A H2SO 4 

## N/A N/A NJA N/A H2S 

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

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

## N/A NJA N/A NJA 

# •

PM

- Particulate Matter PMlO - Particulate Matter less than 10 microns in size PM2.s- Particulate Matter less than 2.5 microns in size SOx

- Sulfur Oxides NOx

- Nitrogen Oxides CO

- Carbon Monoxide VOC

- Volatile Organic Compound Pb

- Lead and lead compounds NH3

- Ammonia Fluorides

- Gaseous and particulates H

2S04 - Sulfuric Acid Mist H

2S - Hydrogen Sulfide TRS

- Total Reduced Sulfur RSC

- Reduced Sulfur Compounds 

# •

•

# • Instructions Use ofThis Form
• Proposed new construction ormodifications should first be evaluated to determine ifthe change is major under the major NSR program 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 FederalMinorNSR Rule (40 

## eFR 49)

- This is not a comprehensive list. 

# • 40 CFR 

### 49.152(d) • Modification means anyphysical oroperational 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 ofany regulated NSR pollutant not previously emitted. 

# • The following exemptions apply: (I) A physical or operational change does not include routine maintenance, repair, orreplacement. (2) An 

### increase in the hours ofoperation or in the productionrate is not considered anoperational change unless such increase is prohibited under any federally-enforceable permit condition or other permit conditionthat 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 dermed in §52.21 (b)(l6), except that the allowable emissions for any emissions unit are calculated considering any emission limitations that are enforceable as a practical matter on the emissions unit's potential to emit.
• 52.21 

### (b)(1 6)

- 

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

# • (i) The applicable standards as set forth in 40 CFR parts 60 and 61; (ii) 

### The applicable State ImplementationPlan 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 70fl5 

# •

# • A. General Facility Information 1. CompanyName & 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 namefor theoperation (i.e., asphalt plant, gas station, 

### dry cleaner, sand & gravel mining, oil and gas wellsite, tankbattery, etc.). 4. Portable Source: Does the facility operate in more than one location? Someexamples ofportable sources include asphalt batchplants and concrete batchplants. 

### S. Temporary Source: A temporary source, in general, would have emissions that are expected last less than 2 years. Doyou expect to ceaseoperations within the next 2 years? 

# • 6. NAICS Code: North American Industry Classification System. The NAICS Code for your facility canbe found atthe following link 

### 7 North American Industry Classification System (http://www.census.gov/epcd/naics/nsic2ndx.htm#SI). 7. SIC Code: Standard Industrial Classification Code. Although the newNorth American Industry Classification System(NAICS) has replaced the SIC codes, muchoftheClean Air Act permittingprocesses continue to use these codes. The SIC Code for your facility canbefound at the following link 

### 7 Standard Industrial Classification Code (http://www.osha.gov/pls/imis/sicmanual.html). 8. Physical Address: Provide the actual address ofwhere the facility is operating, not the mailing address. Include the State and the ZIP Code. 9. Reservation: Provide the name ofthe Indian reservation within whichthe facility is operating. 10. County: Provide the County within whichthe facility is operating. lla & lib. Latitude & Longitude: These are GPS (global positioning system) coordinates. This information canbe provided indecimal format ordegree-minute-second format. 12a

- 12d. Section-Township-Range: Pleaseprovide these coordinates in 114 SectionlSection/TownshiplRange. (e.g., SW V4, NE V4/S36ITIONIR21E). 

# •

Page 8 oflS 

# •

# • 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 information requested in full. 1. 

### Company Contact: List the full 

### name (last, middle initial, fIrst) ofthe owners ofthe facility or the 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 receive requests for data and information. 4. 

### Compliance Contact: The compliance contact must be the local contactresponsible 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 onthe form and described below. The information should be presented in enough detail to document how the facility is currently operating and/or how it is proposed to operate. 

### '" FORM SYNMIN Ifsynthetic minor limits are being requested, we recommend that the information from checklist tiled Form SYNMIN be included with this application. '" Narrative description ofthe proposed productionprocesses. 

# • 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 to help in understanding the proposed facility and how it will be operated. For example: What are the raw materials? What are theproperties ofthe raw materials? Does the production process include heating, drying, the application ofchemicals, etc? How will the raw materials be affected by this process? What are the out puts from each step ofthe process (i.e., crushed ore, dry gas, water, etc...)? Etc
.... 2. The proposed operating schedule presented in terms ofhours perday, days per week, and weeks per year. 3. A list ofthe type and quantity offuels and/or raw materials used. Each fuel and raw material should be described in enough detail to indicate its basic chemical components. Page 9 ofl5 

# •

# • ./ A process flow chart identifying all proposedprocessing, 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. Thehourly, daily and annual maximum firing rates for each fuel and combustion equipment. 3. The capacity for storage units and the hourly, daily and annual maximumthroughput ofmaterial in the storage units. 4. Material andproduct handling equipment and the hourly, daily and annual maximum throughput ofmaterial and product. 5. Tank designs, tank storage capacities, hourly, daily and annual maximumthroughput 

# • ofmaterial and product. ./ 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 emission unit and air pollution generating activity. I. Include manufacturer specifications and guarantees for each control device.



# •

Page 10 of 15 

# •

# • Criteria Pollutant Emissions Estimates**~** Estimates ofCurrent Actual Emissions, Current Allowable Emissions, Post-Change Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants: particulate matter, PMIO, 

### 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 (H2

### S04), 

### 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 pollutants proposed and/or affected by the limitation and bepresented in short term (e.g. pounds perhour) as well as annual (tons per year) units. 3. Any emission estimates submitted tothe 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 • Otherproceduresto estimate emissions specifically approved bythe Regional Administrator. 4. Guidance for estimating emissions canbe found at http://www.epa.gov/ttn/chiefletpac/index.html
. Current Actual Emissions: Current actual emissions for a pollutant is expressed in tpyand generally is calculated by multiplying the actual hourly emissions rate in pounds perhour (lbslhr) times actualhours operated (which is the number ofhours in a year) and dividing by 2,000 (which is the number ofpounds in a ton)
. 

# • 1. For an existing airpollution source (permitted and unpermitted) that operated priorto the application submittal, the current actual emissions are the actual rate ofemissions for the preceding calendar year and must becalculatedusing theactual operating hours, production rates, in-place control equipment, and types ofmaterials processed, stored, or combusted during the preceding calendar year. The emission estimates must be based upon actual test data or, in the absence ofsuch data, upon procedures acceptable to the Regional Administrator. Current Allowable Emissions: Current allowable emissions for a pollutant is expressed in tpyand 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 by 2,000 (which is the number ofpounds in a ton). 1. "Allowed" means the source is restricted bypermit conditions that limit its emissions and are enforceable as a practical 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 source that operated prior to the application submittal, the current allowable emissions are the allowablerate ofemissions for the preceding calendar year 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 calendar year. 

### 3. For an existing air pollution source that does not have anestablished allowable emissions level prior to the modification must report the pre-change uncontrolled emissions. Post-Change Potential Emissions (Potentialuncontrolled 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 tpyand generally is calculated by multiplying the maximum hourly emissions rate in pounds perhour (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 a pollutant is expressed in tpy and generally is calculatedby multiplying the allowed hourly emissions rate in pounds perhour (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). 1. Unless the source is restricted bypermit conditions orotherrequirements 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 beproposed. 2. For physical or operational changes at minor sources and for minorphysical oroperational changes at major sources, the total increase in allowable emissions resulting from your proposed change would be the sum offollowing:
• For each new emissions unit that is to be added, the emissions increase would be the potentialto 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 afterthe change orreplacement minus the allowable emissions priorto 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 orreplacement, use zero in the calculation. • For eachunpermitted emissions unit (i.e., a unit without any emissions limitations before the change) that is to be changed orreplaced, the emissions increase would be the allowable emissions ofthe unit afterthe change orreplacement minus the potential to emit prior to the change orreplacement. However, this may not be a negative value. 

### Ifthe allowable emissions ofanemissions unit would be reduced as a result ofthe change or replacement, use zero in the calculation.

Page 12 of15

# • ./ Modeling Analysis Do I need to do a modeling analysis? The Federal Minor New Source Review Regulations at 40 CFR 49.159(d) requires that a modeling analysis (AQIA) ofproposed emissions be performed ifthere is reason to be concerned that new construction would 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 or contribute 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 8requests that those proposed activities that meet the following criteria perform an 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 or increments in circumstances such as: (a) Asubstantial portion ofthe new or modified 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 inclose 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 EPA Region 8'sModeling Lead: 

# • Gail Tonnesen Region 8 Modeling Lead Tonnesen.gail@epa.gov 303-312- 6113

Page 13 of 15 

# •

## ----

---- I 

# • What Kind ofAir Quality Modeling Analysis Is Needed? 1. EPA Region 8 considers a stepped orphased approach to modeling to be appropriate, as follows: Step 1: Qualitative Air Quality Assessment Step 2: Screening Modeling Analysis Step 3: Preliminary Modeling Analysis (refined modeling) Step 4: Full Impact Modeling Analysis (refined modeling) Step 5: PSD Increment and NAAQS Analysis Step 6: Additional Impact Analysis 

### 2. Step ]: Qualitative Air Quality Assessment Narrative description ofthe current air quality conditions and the expected impact the permitted source would have onthat air quality. Some suggested factors to consider in the qualitative discussion could 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. Step 

### 2: Screening Analysis Forproposed new or modified sources that meet the modeling requirement criteria identified above, protection ofair quality from proposed emissions may

### be shownby using a simple screening technique (e.g., SCREEN3 orAERSCREEN). Screening models are available for download at the EPA SCRAM website: http://www.epa.gov/ttn/scramldispersion screening.htm A pre-approved modelingprotocol is not necessary prior to conducting a Screening Analysis. 4. Ifthe proposed new or modified emission increases do not increase ambient concentrations ofa pollutant by more than the significant impact levels, as compared to the SILs identified below, no 

# •

further modeling is necessary. 

### S' 'fi I

19m 

### leant mpact 

### Leve s Pollutant Averaging Period 1hr I 3 hr 

### S02 

### ! PM2 .5 

### PM 10 

### N02 CO 24hr Annual

24 hr Annual

24hr Annual

1hr Annual

1hr 8 hr 

### Class II Area SIL (ug/m3) 3 ppb or 7.8 uglm.l (interim) 25 5 1 0.07 0.06

5 1 4 ppb or 7.5 uglm.l (interim) 1 2,000 ppb 500ppb Note: The Class I area SILs are provided as guidance and have not been formalized by EPA. 

### ClassI Area SIL (uglm3) 

# • 1.0 0.2 0.08 I

1.2 I 0.3 0.2 0.08 0.08

Page 14 of15 

# •

# • 5. Sources that cannot demonstrate protection ofair quality using a screening technique should continue to the modeJing 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 3through Step 6) to obtain anapproved protocol. 

### What Should I Include InMy Application 

## IfModeling Is Necessary? I. ApprovedModeling 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 until the protocol has been approved
. 

# • 2. Modeling Results In an cases, the modeling results should include the name ofthe model used, all input parameters, and the resulting output. Electronic copies ofthe modeling input/output files should be provided to EPA Region 8 . 

# ./ ESA The Endangered Species Act requires us, in consultationwith the U.S. Fish and Wildlife Service and/or 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 ofyourproposed construction, we encourage you to identifY any listed species that you may be readily aware ofthat could be affected by your proposal. The following website hasbeen provided to assist you: http://www.fWs.gov/endangered! Simply enter the State and County in which you propose to construct to obtain a general listing
. 

# • ./ NHPA The National Historic Preservation Act requires us, in consultation with State and!or Tribal Historic Preservation Officers to ensure that actions we authorize are not likely to affect cultural resources. 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 by your proposal. The following website has been provided to assist you: http://nrhp.focus.nps.gov/natreghome.do?searchtype=natreghome Simply enter the State and County in which you proposeto construct to obtain a general listing.

Page 15 of 15 

# •

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

## Checklist

- Synthetic MinorLimitRequest (Form SYNMIN) Use ofthis information request form is voluntary and not yet approved by the Office ofManagement and Budget. 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 providing the information requested may help expedite the process. Use ofapplication forms for this program is currently under Office ofManagement and Budget review and these information request forms will be replaced/updated after that review is completed.
. Please submit informationto following two entities:

Federal Minor NSR Permit Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129



### A. GENERALINFORMATION

B. ATTACHMENTS Foreach criteria airpollutant, hazardous airpoUutant and for all emission units and airpollutantgenerating activities to be covered by a limitation, include thefoUowing: ./ Item 1 - Theproposed limitation and a description ofits effect oncurrent actual, allowable and thepotential to emit. ./ Item2 - Theproposed testing, monitoring, recordkeeping, and reportingrequirements to beused to demonstrate and assure compliance with the proposed limitation
. ./ Item 3 - A description ofestimated efficiency ofair pollution control equipment under present 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 ofthe potential emissions ofGreenhouse Gas (GHG) pollutants before and after proposed emission controls. 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, EPARegion 8 Tribal 

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



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# • CompanyName Dakota-3 E&P Company, LLC FacilityName WolfChief27-34H Pad Company Contact orOwnerName JoDelI Mizoue Title StaffEnvironmental Snecialist Mailing Address 100I 17th Street, Suite 1200Denver, CO 80202 Email Address JoDell.Mizoue@Williams.com TelephoneNumber (303) 606-4056 ! Facsimile Number 

## I (303) 692-8285

# • Instructions Use this form to provide general and summary information about the synthetic minorNSR source (facility orplant) on Triballands and to indicatethe emissions limitations requested. Submit this form once, in addition to FORM NEW, for each synthetic minorNSR sourceon Triballands.
1. Who Can RequestFederally-Enforceable Limitations Under the Tribal NSRAuthority? The Tribal NSR Rule applies only to sources located within the exterior boundaries ofan Indian reservation in the United States ofAmerica orother lands as specified in 40 CFR part 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 orin trust) does not affect how the rule applies. 2. Who Might Want to Request Federally-EnforceahleLimitations? The primaryreason for requesting federally-enforceable limitations is to avoid an otherwise applicable federal Clean Air Act program, rule orrequirement. Many federal CleanAir Act programs use a source's "potentialtoemit" (PTE) air pollution to 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 oftheequipment and operations. Emission oroperational limits can also be taken 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 PTE to determine whether they apply are (1) 

### the Prevention ofSignificant Deterioration (PSD) construction permitting program, (2) the Title V operating permit program, and (3) the Maximum Achievable Control Technology (MACT) program. For example, existing sources that are considered "major" for Title V (meaning they have the potential to emit airpollution at levels defined in that rule as "major") must apply for a Title V operating permit. Ifa source accepts a federally-enforceable limitationthrough a synthetic minor NSR permit that 

# • reduces their PTE to below the "major"threshold, and the source does not meet any ofthe other requirements that would trigger applicability to the part 71 program, then the source no longer needs a Title V operating permit. Whenplanning for the construction ofanew source orexpansion ofan existing source, a source can also accept limitations onPTE (using a synthetic minor NSR permit) that allow the sourceto avoid PSD. Limitations onPTE can similarly help a source to avoid new MACT standards that would otherwise apply to the source. 3. Section B. AITACHMENTS This section lists the informationthat 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 by the 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. In that 

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# • 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 or potential 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 aHow the source to avoid an otherwise applicable requirement. The information presented must clearly explain how the limitation affects each emissionunit and each air pol1utant from that emissionunit. Use the information provided in response 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 or process parameters that will be relied onand should address frequency, methods, and quality assurance. 

# • Item 3 - The application must include a description and estimated efficiency ofairpollution control equipment under present or anticipated operating conditions. For control equipment that is not proposed tobe 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 the proposed limit, address both current and future descriptions and efficiencies. Include manufacturer specifications and guarantees for each controldevice. 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. (i.e., manufacturer specifications). 

### (iv) Other engineering calculations; or (v) Other procedures 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 generaHy is calculated by multiplying the allowed hourly emissions rate in pounds per hour (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). Item 5

- Newconstructionprojects that have the potentialto emit GHG emissions ofat least 100,000 tpy C02e and 100 or250 tpy on a mass basis, modifications at existing PSD facilities that increase GHG emissions by at least 75,000 tpy C02e and minor sourcesthat increase GHG emissions by at least 100,000 tpy C02e and 100 or 250 tpy on a mass basis are subject to PSD permitting requirements, even ifthey do not significantly increase emissions ofany otherpollutant. As such, any requested limits to avoid PSD must take into account greenhouse gases. Therefore, please include in your permit 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 

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# • 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 C02

### e 3. Nitrous oxide (N2 0) and its C02e 

### 4. Hydrofluorocarbons (HFCs) and its C02e 5. Perfluorocarbons (PFCs) and its C02e 6. Sulfur hexafluoride (SF6) 

### and its C02e 

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•



# • Page 4 of4

## WOLFCHIEF27-34H 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



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

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# ATTACHMENT A: APPLICATION REPORT 

# I

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

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APPLICATION FORAN NSR PSD/TITLE V SYNTHETIC MINOR AIR QUALITY PERMIT WOLF CHIEF 27-34H PAD OIL & 

# GAS PRODUCTION FACILITY 

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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 

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# • 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 Internal 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 Internal 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 Produced Casing Head Gas Emergency Utility Flare
.............................. 15 

# • 6.4 Rice Engines
............................................................................................ 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
Wolf Chief 27-34H Pad 12/29/11 pg. ii NSR Synthetic Minor Permit Application Project #: WEP211324 

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# • 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 Gas Analysis 

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



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Wolf Chief 27-34H Pad 12/29/11 pg.iii NSR Synthetic Minor Permit Application Project#: WEP211324 

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# • 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 Wolf Chief 27-34H 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 limit the emissions from the facility to below the PSD and/or Title V major source thresholds. These limits can be found in Section 4.0 ofthe application. 

## 1.2. Site Location The Wolf Chief 27-34H Pad is proposed to be located in the northeast 

## X of the northwest 

### Y. Section 27, Township 149 North, Range 93 West, Dunn County, on the FBIR in North Dakota. 

## 1.3. Site Description At the proposed Wolf Chief 27-34H Pad there will be six 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. Wolf Chief27-34HA 2. Wolf Chief 27-34HC 3. Wolf Chief 27-34HD 

# • 4. Wolf Chief 27-34HW 5. Wolf Chief27-34HX 6. Wolf Chief27-34HZ 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.

WolfChief27·34H Pad 12/29111 pg.1 NSR Synthetic Minor Permit Application Project#: WEP211324 

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# • 2.0 NARRATIVE DESCRIPTION This section of the application provides a detailed description of the operations at the Wolf Chief**27~34H** 

### Pad. For purposes of estimating emissions from this facility, the combined first twelve-month potential production from the six 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. 6 - Heater Treater/Separators 6 - Line-Heaters (0.75 MMBtu/hr max) 24 - Oil Production Tanks 1 - Gasoline Recycling Pump 6 - Produced Water Tanks 6 - Electric Lifting Units 6 - Oil and Gas Producing Wells 1 - Truck Loading Rack 1 - Manufactured Produced Gas Flare 6 - Diesel Engines 1 - Manufactured Enclosed Tank Vapor Combustor 

### The Oil/gas/water emulsion being produced from the wells is transported up each weIIbore 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 onsite 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 Wolf Chief27-34H Pad 12/29111 pg.2 NSR Synthetic Minor Permit Application Project#: WEP211324 

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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.



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pg.3 Wolf Chief 27-34H Pad 12/29/11 NSR Synthetic Minor Permit Application Project#: WEP211324 

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# • 3.0 POTENTIALTO EMIT ESTIMATE 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 Wolf Chief 27-34H 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. 

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WolfChief 27-34H Pad 12/29/11 pg.4 NSR Synthetic Minor Permit Application Project#: WEP211324 

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••••••••••••

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Figure 1: Example ofMaximum PTE from a Seven Well Pad 

# Example of**Maxif!l_~11'!** 

# PTE from a Seven Well Pad 6,000**.~All** seven wells begin production 5,000 

### simuJtaneoUsfV 

# + R'OOO co • 

# 1000 • ct' • • Total Production trom Seven WeUs on Pad 

# i 	 • & .4L 2,000 :- ......

1,000

- -......-,....

### ............



## o o 10 20 30 40 Month

Wolf Chief 27-34H Pad 12/29111 pg.5 NSR Synthetic Minor Permit Application Project #: WEP211324

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# • 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 

## i a.. II 2,000 

### If 

# .. 5th well begins production

2nd well begins production 1st well begins production -t'-Total Production from Seven Wells on Pad

## ~ -12-Month Rolling Average 011 Production 2:­ 

## -= 1,500 c -12-Month Rolling Average 011 Production Limit o ::E 1,000

500



### o o 5 10 15 20 25 30 35 40 Month Wolf Chief 27-34H Pad 12129111 pg.6 NSR Synthetic Minor Pennit Application Project#: WEP211324

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# • 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 StorageTankVOC 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 oillgas/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 WolfChief27-34H Pad 12/29/11 pg. 7 NSR SynthetiC Minor Permit Application Project#: WEP211324

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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 InternalCombustion 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 External Combustion Unit Emissions 

# • The natural gas external combustion units at the facility are the heater treater line­ heaters. 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 TruckLoadingEmissions 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 Fugitive Emissions: 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. 

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Wolf Chief 27-34H Pad 12/29/11 pg,8 NSR Synthetic Minor Permit Application Project#: WEP211324 

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4.0 EMISSIONSAND OPERATIONALLIMITS REQUESTS Oatoka-3 is requesting emissions and operational limits at the Wolf Chief 27-34H 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 PSOlTitie 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: 24.45 tons per year ofVOCs and 0.34 tons per year of HAPs. 

## 4.2 Reciprocating Internal Combustion or CompressionIgnition Engines Oakota-3 will be required to limit the emissions from any reciprocating intemal 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 

# zzzz., as applicable. 

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Wolf Chief 27-34H Pad 12/29/11 pg.9 NSR Synthetic Minor Permit Application Project #: WEP211324 

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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, PM 10, 

### 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. Oakota-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 MMBtulhr heater treater line-heaters) at the facility; therefore, the emissions estimate is equal to the uncontrolled potential to emit.

WolfChief 27-34H Pad 12/29/11 pg. 10 NSR SynthetiC Minor Permit Application Project #: WEP211324 

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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 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 on the location. 

## 5.7 Diesel Storage TankEmissions 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.


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WolfChief27-34H Pad 12/29/11 pg. 11 NSR Synthetic Minor Permit Application Project#: WEP211324 

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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 

# voe 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 

# voe 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 standing/working/breathing losses and flashing emissions; or f. Other methods approved by EPA.
WolfChief 27-34H Pad 12129/11 pg. 12 NSR Synthetic Minor Pennit Application Project#: WEP211324 

# •

# • Recordkeeping Reguirements: In order to demonstrate compliance with the 12-month rOiling 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 C of this application, the total VOC, 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 Control Device The limits requested on the emissions from the storage tanks are directly dependent on the production throughput in the tanks. All emissions at the fadlity will 

### be controlled in one or more enclosed combustors and/or utility flares that are 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 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 

### °C, or ±2.5 

### °C; 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. WolfChief 27-34H Pad 12/29111 pg.13 NSR Synthetic Minor PermitApplication 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 oftime 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 ofthe 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 Hame in the enclosed combustor or utility flare is not operational, the time period during which it was not operational, and the corrective measures taken. WOlf Chief 27·34H 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-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 

## vac (or 

## vac 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. Wolf Chief 27-34H Pad 12129/11 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 

### ec, or ±2.5 

### ec; 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.


# • Wolf Chief 27-34H Pad 12/29111 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. 

# • 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, Oakota-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, Oakota-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. Oakota-3 will keep all input parameters and calculations used to determine the monthly emissions. 

## 6.7 Fugitive Emissions: EquipmentLeaks Oakota-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, Oakota-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. Oakota-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. Oakota-3 will make the first attempt to repair any leaking equipment within five days after the Wolf Chief 27-34H Pad 12129/11 pg.17 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •
leak is detected. Dakota-3 will minimize leaks of volatile organics from each piece of equipment in hydrocarbon service at this facility. Monitoring Reguirements: a. Dakota-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. Dakota-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 ofeach inspection. Recordkeeping Reguirements: WolfChief 27-34H Pad 12/29/11 pg. 18 NSR Synthetic Minor Permit Application ProjecU: WEP211324 

# •

# •

a. Dakota-3 will document and maintain a record ofeach 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 

## vac (or

## vac, 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 new twelve-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. 

# •

Wolf Chief 27-34H Pad 12/29/11 pg.19 NSR Synthetic Minor Permit Application Project #: WEP211324 

# •

# •
7.0 QUALITATIVE AIR QUALITY

## ASSESSMENT 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.



# •

WolfChief27-34H Pad 12/29/11 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 ofdesignated critical habitat ofsuch 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 ofeach 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.



# •

Wolf Chief 27-34H Pad 12/29/11 pg.21 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 9.0 NATIONAL HISTORIC PRESERVATION ACT 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 

### //I 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. 

# •

•

WolfChief27-34H Pad 12129/11 pg.22 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •

ATTACHMENT B: EMISSION INVENTORY



# •



# •

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

# •

# • • • 

# •

[**-~---~-----** 

# - 081<018:'3 E&P Company, LLC ---

# J Input Data GREEN

### = Require. Input RED =No input required. Thi. is a calculatedvalue. Facility Information**Olf** Chief27·34H Pad

ss<>eiated Wells: olfChief27·34HO. 27·34HZ. 27·34HC. 27·34HX, 27·

# ~ 34HW,27.34HA oIlIItlicllly
.....1IIt
............r.**~1i/II(** ...**~uctIonorlht_oflMCl_ofllltfoclll.y.** __ ___ _ Not Producing Yet

# ~ 

# l

MSiii l!!..i'Oductlori DIIIt8 BOPD 2745 3949 0.505 _ In borroIo01011

.......**temr""lIItllnd_oI~.** Bandon
... _prmouolrpraduolng
.....InIht._IIoIcI
.............lIon. doIIyjll'1lClu<l!lon01 """ In MocI
....dor,
.... oftliltpnodlclod lindSO cloy. ofproduction. PO , .... on liltpnocIo1ocIllntUO cloy. ofproduction.
lMiusted BOPD lMiusted Produced Gas (Mscfd) Decline Factor 1996 1387 

## rn... tho
.........BOPD
.........loboprodUClduolngtho
.......... doc
... llIcIor. fn,1o 10tho
.........""""01""" Ihtl0III10
......... 10produc<t
..lngtho
... _Nd
.......

## '*""'. OlllCondenuteTlnk Data Desc:rlPtIon Flash Gas Method: Proe:eu Simulator Ihtdrap
............ 10

__tho opprop_lIoohgoo 1IIIIIhod. Proe:eu Simulator Estimated scf/bbl 40.23 lTh
..cMlblfrollldlnot_u
..fllllllor
..**~--..** Bandon

__ WTlllkEmiulonSummoryOulpUt. Estimated Tlnk Vapors (scfd) 88271.137fn,1o10 liltIOIIoMIIkIICIcIoU"vapo.......Ofttho foIowIng: 1dJ\IIIodBOPD IIIIIIIIp1Iodbythooc:MIbI_NdonLlMI. Lower Heating Value 2401.97 W TIIIUmiulon SutftmoryOUtput. p.-r............. (IIIIiIcI\ofllllkvapolLlIoMdon**~** Molecular Weight 42.14
.........wlghtolthoIInkvapo
.. 1npoundo
....poUJld.molo**(MI-molo~** BIoollon W TankEmloolon Sa..-.yOutput. IVOC% 74.026 I \IOCW.IghUNcllonollhtllllkvaporgoo(CI+I.BIoodon

__.WTlnkEmiulonSutftmoryOutput. !'Loc TPV/BOPD Emiuion Factor 0.613 I W TlI1kE_n su_OulpUt. (Su_outputc_.a-lIIoIIonohip -. TPY
..... BOPD) e-d on __ HAP% 1.046 E&P rinkEmloolon Su_Output.**~wIght** tr.ctIon01thoIIIIkvaporgoo. Blood on ....._ HAP TPY/BOPD Emission Factor 0.009
.......on

__ W TlllkEmIooion S""""""output. (Su_outputc_. a­ ..loIIonohip -. TPV
.....BOPOj C02% 0.26% wlghtfMcllonofthoIIIIkvaporgoo. Bandon _ .... W TlllkEmIooion 8ulllmoryOulpUt. CH4% 1.99%**~wlghtfMcllon** ofthoIIIIkvaporgoo. Bandon
.............WTlI1kEmIooIon

## s_ Output. H:rS Might% 0.09% 

### faawoIgIIt......"t

# 01thoIIIIkvaporgoo. Bloodon ......... E&PTlllk Emllloion Su
..mory Output. H:rS ITIOIe % 0.10% 

### firs
..... ......"toftho linkvapor goo. Blood on ....._ W TOIIkEm_ 8_Output. Enclosed Smokeless Combustor Control Destruction Efllciency 98% __tho ",",_omIoolonoonIroIte.**~01_""''''''''.** Th.loallxod
..........booodOhoonlnll••**~..,.** down_lo

# • • Dakota-3 E&P Company, LLC 

# 'J Input Data GREEN = Requires input Facility Information RED =No input required. This IIa calculated value. WolfChief27·34H Pad Associated Wells: WolfChief27.34HD. 27.34HZ. 27.34HC. 27·34HX. 27· 

# [.h

__h
.._. I 34HW.27-34HA Treater Gas Data Deacrlptlon Btu/scf 1700.39**~of"""""_IF"'m",,_nokl!llllN/yllt)** MolecularWelaht 29.65 A_InOlooulorwolghtoftho """"""""goo In 1bIIHno1e.1F_rap""'

__IIIMWyaIo) SpeeiI\c Gravity 1.02**~** _Ill tilCOnveltlpocllc gI\I¥IIy II>
...looulorWlighl, _rtho gravlly oftho...nmum,...IF",m rap_ftokl
...MWyaltj Average MolecularWeight 29.65 IF
...mnop

__goo_lyMtj VOC% 45.94% voc...**lght~oftho"""""goo(Nolo:Welght'A.notMolo%).IF"'m~_a** ..**~)** HAP% 1.28% HAP**~~** oftho""""'" goo. (Nolo: WoIgI1t'A. not**MoIo%~** (F",,.. ""

__ goo MWyaIoI C02% 0.863%**C02wo1ght~ofthoWlftotrumgoo.** (Nolo: WoIgI1t'A.**notMolo%~** (F",,.. ",,_noklgooMWyaliol CH4% 25.747%**CIM~_n** cAtho...a.­
_ (Nolo:WoIgI1t'A. notMolo%). IF
...,.. nop_ftokl !IIIlnaIyolt)**H~_ight%** 0.000% H,!I Wllghtpon:anlcAtho...a.-!III. IFrom rap

__ ...MWyaliol H2SmoIe % 0.000% H,$
......PI- cAthowoIo!rumgoo. IF,,,mnop_IIoId!lllMWyaIo) Connected to sales line lIMtho drop
......nN/tilchooHtho
.......rilIo om_Ion**control~** ControllCaPIUre Efficiency 100"/0 JWIod II!pili
..... --' 1Mco.... cA_. ftond, control oIIIclllnc:ycAonyoppIIcoblo controII Ccomb
......,pitno..,ulllItYftora,**.~** Treater Bumer(.)



# • Total Btu/hr



# • 4500000 Daecriptlon 0lIlbumormfnafortho hNIIr_bu""""llnbIuI1Y••_ ............bu""ra,odd tho..,hutInpUltogothor. tThabUrrw(I)1IIoro

___ 10

__ .,710 houraporVOlt. Hours ofOperation 8,760 Truck Loading Da.crlptlon Oil IIlIOId throuah LACT lIMtho
_ down_10 """-thoIIPPlIIPrilIo
..... 1IIIIhod.• oliotold 1hIouah.LACT no 1nJwt
........... .-.!nodIn 30-35. Submerged loading: dedicated normal servica 0.6 lIMtho
_ ......llItlochooHthollPPlIIPrilIo
.... of
.......1I.ThI uIInIIoft"'*>r••

# _.......,IMt
......... IIaIedon .... of
........ I 42.14 MoIIcIIlorw.lghtof1lnk_raln 1bIIHnoIo.""'-
_ .............woIght

### lI
..hlng

### ._10""""'""""

__E&P Ton'" doIa. MolecularWeight

IPl1eURuIdCpu.,..paand Contollera[NOne'_. 

### -:J**IG~ol** Dahydretor (None) I Vapor Pressure 

## ...._,p........ 01JIquId
.........po.....Plr_lnch
..........(POll)lno
....pociIIc
... lII
........... .... 1oT
.....2on Truckl<>odlng" Temperature 2.30
'
........... cAbulkllquldloododln F
.......... 1IO
....pocIIcdoIolt
........_ .....___I......-.... 50.0D Loed Rate (bbllhr) 18D '-'*t liiiocAlquklloodod III
.......porhour. Load Time (hrs) 1.00 

## rn..u... K
......10bIdoutono
.....**(hn~**__ __ __ 

# • •

OillCondensale Tanks CasinQ Head Gas Treater Burner RICE Engine Truck Loadino Fuel Storage Tank Pneumatic Pump Pneumatic Controllers GIvcoI DehYdrator ITotaIIITP!l 

## I I

OillCondenseteTanks Casino Head Gas Treater Burner RICE Enaine Truck Loading Fuel Storage Tenk Pneumatic Pump Pneumatic Controllers Glycol DehYdrator**ITotalla~** VOC 1222.40 18.19 0.11 6.80 N/A NegliQible

N/A N/A NIA 1247.50

VOC 24.45 18.19 0.11 6.80 NlA Neafiaible

N/A NlA N/A 49.55 

# • 

# r

I Da-k;;t;:3E&P

# Compan~, LLC

# II
FacIHIy:

olfChief27-34H Pad

..oclatedWells: oIfCIIIef27·34HD. 27-34HZ, 27-34HC. 27-34HX, 27-34HW. 27-34HA 

### Emission Summary Uncontrolled Potential to Emit Criteria Pollutants HAP NOlI PM PM10 PM2.5 17.04 N/A N/A N/A N/A 0.51 2.93 0.19 0.19 0.19 0.04 1.93 0.15 0.15 0.15 1.02E-01 26.09 0.15 0.15 0.15

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

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

## II 17.88 

## II 30.95 

## I I 0A9 

## I I 0.49 

## I I 0.49

HAP 0.34 0.51 0.04 1.02E-01

NIA Negligible

N/A NlA NlA NOlI 2.39 2.93 1.93 26.09 N/A N/A N/A N/A N/A 0.99 33.34 

## I I 

## I I Allowable Potential to Emit Criteria Pollutants· PM 0.11 0.19 0.15 0.15 NlA N/A N/A N/A N/A 0.80 

## I I PM10 0.11 0.19 0.15 0.15 NIA NlA N/A NlA N/A 0.60 PM2.5 0.11 0.19 0.15 0.15 N/A NlA N/A NlA N/A 0.60 

## I I I I



## I I co N/A 15.93 1.62 43.08 NIA N/A N/A NIA N/A 60.63



### co 13.02 15.93 1.62 43.08 NlA N/A N/A NlA NlA 

### I I



## I I H.s N/A NA N/A N/A N/A N/A N/A NIA N/A 0.00

HtS N/A 0.00 N/A NlA N/A NlA N/A NlA N/A 502 N/A 0.00 0.Q1 1.24E·01

N/A N/A N/A NIA N/A 0.14

502 N/A 0.00 0.01 1.24E·01

NlA NIA N/A N/A NlA 0.14 

# •

HCHO Negligible

0.00 Negligible

0.10 Nealiaible

N/A Nealiaible NegliQible Nealioible 

## I I 0.10

HCHO Neolioible

0.00 Negligible

0.10 Negligible

N/A Negligible Nealiaible Negligible

0.10**!'~.j.'.~"";'Y'1"::Y~"""''''''''''''''''_~'''''''f'''-~~N''''r''~ ''!''!M'!0'''''''I''O,_''''''''''''~''m!'''""",,,"** ..._<:,t1·
.....f,..._' I\ •••**i""'_'_""~!:"!P"' \1I:~'I\I(/~,**  73.85 0.00 'Emissions Of laed and lead compounds. ftuorid
.., sulfuric acid mist, lotal nsduead suWur, Bod nsduead sulfurcompounds
...assumed 10 be ""giligable for upstraem oil & gas operations on Ihe FBIR.

# • 

# • Oit/Condensate Tanks Casing Head Gas Treater Burner RICE Engine Truck Loadina Fuel Slorllg8Tank Pneumatic Pump Pneumatic Controllers Glvcol Dehvdrator

7373.79 1627.95

No Potential To Emit Actual Greenhouse Gasesb Greenhouse Gasesb co2 CH. N20 cO2 CH. N20 NIA 32.40 NIA 1162.35 0.00 0.03 3054.12 10.20 0.00 3054.12 10.20 0.00 2318.82 0.13 0.03 2318.82 0.13 0.03 2.27E+02 0.34 0.07 2.27E+02 0.34 0.07

0.00 0.00 NIA 0.00 0.00 N/A NfA NIA N/A NIA NlA NIA NIA N/A N/A NIA NIA NIA NIA NlA N/A NIA NlA NIA NIA NIA NlA NlA NlA N/A ,Totals (TP!) 

## II 51100.14 

### , I 43.07 

### I I 0.10 

### I I 7362.99 

### I I 10.87 

## I I 0.13 

## I
GHG M_Emlulona(lIlY): 

# I 5643.81 

# I GHG M •••EmIsIloM (tpy): COlla (tpy): 8535.58 COlla (lIlY): ApplicabletotIM TaIIorInt Rule?:

,



# • • Hydm!luorocmb..,. (HFCs). P8Iflu"""","",ns (PFCsl. and SulfurH
..aftuorid•• (SF6) emissIOns "'"not ""'_f""" O&Gproducllon--.,
. 

# II Dakota-3 E&P

# compan~!L**!:£n** Facility: 

# I
WolfChis'27·34H Pael ",,",«i.!<telw.a.: Wolf Chis'27·34HD. 27-34HZ, 27-341iC. 27-34HX. 21-34HW. 27-341iA

# • 

# • • •

Dakota-3 E&P Company, LLC
Wolf Chief27·34H Pad Associated Wells: Wolf Chief27·34HD. 27-34HZ. 27-34HC. 27-34HX. 27
..34HW-,-27·34HA 

## Tanks

011 ProductionC19i5 -_.BOPl5
.. Flare Gas Volumel--80,276 -Sa§] Lower Heating Value! 2401.91 8MSCI' Molecular Weight[ -.u;14--·· lli/IlHi161ii] voc wt Fraction' 14.03% VOC Emission Factor! 0.613 tpyibOpd I HAPs: Benzene wt Fractiol Toluene wt Fraction E-8enzene wt Fractio Xylene wt Frectio n·Hexane wt Fractio 0.0285% 0.0166% 0.0033% 0.0191% 0.9045% 2,2.4.Trimethytpentane
....**_~~-._.,** wt Fraction! 0.0139% HAP Emission Factor T.Oli9--- tpYliiOp<l] C02wt Fraction! 0.26% ., CH4 wt Fraction! 1.99%**+,)"'~-~"",--"** ..**'1:''''·~~~'''''k'!'_~~-~~.,'4_'''J!>~I''''':~,~~~q~UI.~,''«1,...,,,.,.,,Ii'''_lI!'ItH~_*'''\''IIo!'I!:I~_t'!*'~~E;r_~~~** ___ Controlled emissions are calcutaled based on a**~destruclion** efficiency of lhe VOC gas.

# • 

# • 

# •**I~** 

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

# I

WolfChief 27-34H Pad Associated Wells: Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA

### Tan~ 

## -] CRITERIA POLLUTANT EMISSIONSa Uncontrolled VOCs (PTE): Using E&P Tanks Run: 

## I 0.613 TPV VOCIBOPO 

## I x 11995.43 SOPO x DRE 

## I 0% 

### 1 1222• 40 TPvl I

Controlled VOCs (Allowable):**~sing** E&P Tanks Run: 

### I 0.613 TPVVOCI80PO

## I x 11995.43 BOPO**--~-** x ORE 

## I 98% 24.45 TPvl Uncontrolled HAPs (PTE): Using E&PTanks Run: ORE 0.11 Iblhr 0.011b1hr 0.08 Iblhr 3.361blhr 0.071b1hr 0.271b1hr TPY**~** 3,345 scflhr 3,345 scflhr 3,345 scflhr 3,345 scflhr 3,345 scflhr



# • 3,345 scflhr 

# .. 42.14 Ibl1b-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 0.46 Benzene x x x x 11379 scfl1b-mole 0% 0% 0% 0% 0% 0% 

### =**~** 

# .. 0.05 E-Benzene x x 11379 scf/lb-mole x x 

### =**~** 

# .. 0.27 Toluene x x x x 1/379scfl1b-mole 

### =**~** 14.73 n-Hexane x x 1/379 scf/lb-mole x x 

### • 

### =**~** 

# .. 0.31 Xylene x x x x 11379 scfl1b-mo1e 

### =**~** 

# .. 1.20 2.2.4-Trimethylpentane x = x 11379 scf/lb-mole x x ..!!:Qlli. Uncontrolled TOTAL HAPS (TPV) 

# .. I 17.04 Controlled HAPs (Allowable): 3,345 scflhr 3,345 scflhr 3,345 scflhr 3345 scflhr 3,345 scflhr 3,345 scflhr 11379scfllb-mole 1/379 scfllb-mole 1/379 scf/lb-mole 11379 scl/lb-mole 11379 scfllb-mole 11379 scf/Ib-mole 

# -- 98% 98% 98% 98% 98% 98% = O.OOlblhr O.OOlblhr 0.00 Ib/hr 0.071blhr O.OOlblhr 0.01 Iblhr 

# .. 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 Ib/lb-mol 42.14 lb/lb-moI 0.01 x Benzene x x x 0.03% 

# .. 0.00 E·Benzene x x x x =**~** 

# .. 0.01

Toluene x x x x =**~** 0.29 n-Hexane x x x x =**~** 

# .. = 0.01 Xylene x x x x 

### =**~** 0.02 2.2.4-Trimethylpentane x x x x = 

### =**~** 0.34 Controlled TOTAL HAPS (TPV) 

### =

# - 

# • 

# • • •**.~~"~-":'.,.",,**...



# Oakota-3 E&P Company, LLC
Wolf Chief 27-34H Pad Associated Wens: Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX, 27·34HW. 27·34HA 

### Tanks Uncontrolled NOx: Nox:1 0 scflhr )( 

### I 2.402 0.00 BluIscf

### I
Iblhr )(

)( 1 MMBtull,OOO.OOO BItJ
8760 hr!}! x 

## I )( l 0.000 IbIMMBlu l
1lonI2ooo Ib 0.00
0.00 Iblhr 

### I Tpvl NOx Created by Combustion (Actual) NOx:l 3.345 scflhr x 

### I 2.402 Btu/sct

## I**0.55~1** x

)( 1 MMBtu/l.000,OOO Btu
8760 hr(}'!: )( 

### I )( 

## I 0.068 IbIMMBtu 

## I
1 10n12ooo Ib 0.55
2.39 Iblhr

## I Tpvl Uncontrolled PM: 

## PM:I 0 scflhr x 

## I 7.6 lb/l,OOO.ooo sct 0.00 Iblhr
0.00 Iblhr )( 8760**hr~** x 1tonl2000 Ib 0.00 TPV PM Created byCombustion (Actual) 

## PM:I 3.345 scflhr )( 

## I 7.6 Ib/1.ooo.ooo sct 0.03 Iblhr
0.03 Iblhr x 8760 hr(}'!: )( 1ton/2000 Ib 0.11 TPY**\\1""'''''''';:t''''i'''~i'~!N;·,~.,_t<!"·-1t\1~:W~''~~_''<K,~ft'9'''''~~~'''''''''~~~V'J~~~~~'~'''lw'""'** ..**"_~~_**

# • 

# • • • Dakota-3 E&P Company, LLC Wolf Chief 27-34H Pad Associated Wells: Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA

Uncontrolled CO: 

### co:, 0 scflhr:1 x , 2,402 Btu/sci' x 1 MMBlt.Vl.000.000 Btu 

## :J x 0.3701b1MMBIu , 0.00 lb1hr-j O.OOiblhr:;J x 8760 hrM -:1 x , 1 lonl2000 Ib J rnO-fl'Y,
CO Created byCombustion (Actual) 

### co:, 3,345 scllhr x I 2,402 BIt.VscfJ x 1 MMBtt.V1.000.000Btu 

## :J x 0.370 Ib/MMBlu' ,----ur=iblhr]

,-2;1)7 Iblhr x 8760 hrM x , 1 10012000 Ib ] , 13.02 TPV I "NOx. 502. and CO emisSion factors are from AP42 Table 13.5-1 (Emission Faclors for Flare Operations)
. 

# r**Tan~** 

# I

# • 

# • • •

REGULATED GREENHOUSE GAS EMISSIONSb 

# Dakota-3 E&P Company, LLC
WolfChief 27-34H Pad Associated Wells: Wolf Chief27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 

## Tanks

Uncombusted CO2:
C02:' 3,345 sef"'r 

### I x 11/379 sctnb-mole

## I x 0.98 42.14 Ibllb-mole

### 1
Iblhr x wt x 

### I 0.26% 

### I

8760**h~** x 

## I ORE x 0%
1 tonl2000 Ib 0.98
4.30 Ib"'r
TPY C02 Created byCombustion (Actual)
C02:1 3,345 set"'r x 1120,000.0 Ibl1.000.000 set
401.38 IbI11r x 8760**hr~** 401.38 IbI11r 

### I

x 1 lonI2OOO Ib 11758.05 TPY**~'""J''''''~'·~";''J1'·''''~'''''~''''!$!'\1¥'I'''~l'~;)f~.,,'"'''1'''''~_'\'Il"''~** .•**'~II'*''l1'""~~~~~~~_** }. t**""""'~,~~~.""'~'ftI'I"** ....

# • 

# • Dakota-3 E&P Company, LLC --- 

# I

WolfChief 27-34H Pad Associated Wells: Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-:HHW, 27-34HA



# • 

# .' Uncontrolled CH4: wt ORE CH4:13,34S--Sdlhr:J x**~sCtJib..mof!]** x 42.14 Ibllb=iiiO!el x 11.99% 1 x 0% 7AO Iblhr
7.40 Iblhr x 8760 hr/y!' x 

### I 1 ton/2000 Ib 

### ..! 32.40 TPY Controlled CH4: (Actual) wt% ORE CH4:!**~34S** --SdlhD x 11/379 sdllb-mole 1 x f3[!41611&moIi) x 11.99% 

### I x 98% 0.15 Iblhr 1
0.15 Iblhr x 8760 hr/yr I x 110"l2oo01b 0.65 TPY 

## J**Thn~** 

## -]

# • 

# • • 

# •

[ Dakota-3 E&P Company, LLC
WolfChief27·34H Pad Associated Wells: Wolf Chief27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27·34HA 

## [ ---- Tanks
Uncontrolled N20:
CH4:1 3,345 scflhr x 111379 scfllb-mole

### I x 0.00 42.14 Ibllb-molel
Ib/hr x wt% x 10.00%

### I
8760**hr~** x 

## I ORE x 0% 1 10012000 Ib 0.00
0.00 Iblhr TPY N20 Created by Combustion:
CH4:1 3,345 scfIhr x 

## I 2.3 Ibl1,000.000 sef 0.01 Iblhr 

### I
0.01 Iblhr x 8760 hrlyr x 1**tool~Olb** 

### J O·03

__ 

### nJ C02 and N20 emission factors are from AP-42 Table 1.4-2 (Emission Factors for Natural Gas Combustion).**""'<~"·~"""l"."!"Y~7''''''''''':l"",·t_~~''''''''7.'''~_~_''''~'~~~~~'~,~~~'r'--** ......**~~\'<'.~'~~'':'''I'¥~~,~_~1''l''''''""~~~.1<t~_**

# • 

# • [ Dakota-3 E&P Company, LLC
WolfChief 27-34H Pad Associated Wells: WolfChief27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA

Flare Gas Volumel 5,n9 scflhr J(Takes Into account the 10% ofthe total produced gas volume that is not being sold.) Lower Healing Value'"**-1"'=7::oo~.~3~86""5:::7~1-"'B""tul""'!""scf~""1** Avg. Molecular Weight. 29.65 Ib?l§OOi!l VOC WI**fract lonC~:.94%-:J**  HAP WI fraction Benzene WI fraction E·Benzene WI fraction

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·**Trimethylpentaner-_-=~:r-_-"** WI fractlonJ 0.00% C02WI fractlonC-O:86%-

### -::1 CH4 WI fraction. 25.75% 

### J Hours of Flaring fOlf PTE:I 8760 hoursfyr
Control Efflicien 98% ORE



# • •

# • 

# • •**"'"\""~.J"''',~** 

# •

[ Dakota-3 E&P Company, LLC
WolfChief27-34H Pad Associated Wells: Wolf Chief27·34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW, 27·34HA 

# II Casing Head Gas CRITERIA POLLUTANT EMISSIONSa Controlled VOCs (PTE): voe:1 5,119 scf/hr )( 11/379 scfllb.mole x 4.15 129.64686 IbIIb·mole 1
Ib/hr )( x 8760 hr!)! wt% 45.94%1 )( Control % 

## I 98% 1

x 11 tonl2000 Ib 4.15 18.19 Ib/hr TPY ControlledVOCs (Allowable): voe:1 5.119 scf/hr x 111379 scfllb-mole x

___

4.15 129.64686 Ibllb-moIe 

### I**Ib~** x )( 8760 hrlyr I wt% Control % 45.94%1 )( 1 98% 1

x 11 tonl2000 Ib 

### = 4.15 18.19 Iblhr TPY**"~""·"::".""",\",').l!W",~~C",..,,,,,?,~I"'''!''~)''I''''?,,,?"_\''II!lN''''''''''~:>';'''~~~'~_~·!~'~,~~n"'';'''¢'I.''''il** ••**t''lf.'.'1m~~'''Il',,~,''I~,** 11"( )h;Ji!l,.,**W~7-"**

# • 

# • Dakota-3 E&P Company, 

# LLC-- 

# I

WolfChief 27-34H Pad Associated Wells: Wolf Chief27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 

### Casing Head Gas

5.779 scfIhr 5.779 scflhr 5.779 scf/hr 5.779 scflhr 5.779 scf/hr 5.779 scflhr 5.779 scflhr 0.06 Benzene 11379 scfflb-mole 1/379scfllb-mole 1/379 scfflb-mole 1/379 scfllb-mole 11379 scfllb-mole 1/379 scfllb-mole 7.50E-02 IbfMMscf x 29.64686 IbfIb-mol 29.64686 Ibllb-mol 29.64686 Ibllb-mol 29.64686 Ibllb-moI 29.64686 lb11b-mol 29.64686 lb11b-mol 1000000 scflMMscf x 0.15% 0.01% 0.18% 0.84% 0.10% 0.00% x x 98% 98% 98% 98% 98% 98% 

# . " '" 0.01 Iblhr 0.00 Ibfhr 0.021bfhr 0.081blhr 0.01 Ibfhr O.OOlb/hr O.OOlb/hr



# • 0.00 x E-Benzene = x x x 

### • 0.07 Toluene x x x x " 

# .. 0.33 n·Hexane x x x x " 

# .. 0.04 x Xylene x x x " 0.00 2.2.4-Trimethylpenlane x x x x " 

### " 0.00 Formaldehyde x x = "



# • Controlled HAPs (PTE): Using E&P Tanks Run: Benzene 5.779 scflhr x )( E-Benzene 5,779 scflhr

Toluene 5,779 scflhr x n-Hexane 5.779 scf/hr x

Xylene 5,779 scflhr x 2,2,4-Trimelhylpenlane 5779 scflhr x Formaldehyde 5.779 scflhr 1/379 sclllb-mole wI% Control % 98% 98% 98% 98% 98% 98% TPY 29.64686 Ibllb-mol 29.64686 Ibllb-mol 29.64686 Ibllb-mol 29.64686 Ibllb-mol 29.64686 Ibllb-mol 29.64686 Ibllb-mol 0.06 0.15% 0.01% 0.18% 0.84% 0.10% 0.00% )( x x 0.01 Ib/hr O.OOlbfhr 0.021b/hr 0.08 Ib/hr 0.01 Iblhr 0.00 Ibfhr 0.00 Ib/hr 

### = '" 0.00 )( )( x 

### = '" 0.07 )( x x 

### = '" 0.33 x x x '" 

### " 0.04 x x x 

# .. '" '" 0.00 x x x " 

# .. 0.00 " 1{379 scfllb-mole 1/379 scfflb-mole 1/379 scfllb-mole 11379 scfllb-mole 1/379 scfllb-mo1e 7.50E-02 IbfMMscf 0.12 Iblhr x 8760**hr~** x 11 ton/2OOO Ib 1 0.51 TPY 

## I 1 

## I 

## I 

## I I '" Controlled HAPs (Allowable): Using E&P Tanks Run: wI% Conlrol% TPY



## I 0.12 Iblhr 

## I x 

## I 87601n/l:! 

## I x 

### 11 Ion/2000 Ib 

## I " 

## I 0.51 TPY 

## I

# • • • •

Dakota-3 E&P Company, LLC
Wolf Chief27·34H Pad Associated Wells: Wolf Chief 27-34HO. 27·34HZ. 27-34HC. 27·34HX. 27-34HW. 27·34HA 

### Casing Head Gas
Uncontrolled NOx (PTE): NOx:! 5,779 scflhr x 

### I 1,700 Btulset
0.671b1hr x

x 1 Mmbluf1,OOO,OOO Slu
8760 hr!}! x X 0.068 IblMMBtu 

### I

1 tonl2OOO Ib 

### '" 0.67
2.93 Iblhr TPY NOx Created by Combustion (Actual): NOx:! 5,779 setlhr x 

### I 1,700 Btu/set I 0.671blhr x

x 1 Mmblul1,OOO.OOO Slu
8760 hrll'! x x 0.068 IblMMBtu 

### I

1tonl2OOO Ib 

### " 0.67
2.93 Iblhr TPY Controlled H2S (PTE): H2s:1 5,779 seflhr x 111379 sc:fllb-mole x 0,00 

## I 29.64686 Ibllb-mole 

## I

Iblhr x x
8760 hr!}! wt% Control % 0.00%1 x 

## I 98% 1

x 

### 11 tonl2000 Ib 0.00
0.00 Iblhr TPY Controlled H2S (Actual): H,s:1 5,779 sc:flhr x 111379 sc:fllb·mole x
0.00 

### I 29.64686 Ibllb-mole 1
Iblhr x x
8760 hrll'! wt% Control % 0.00%1 x 

## I 98% 1

x 

### 11 tonl2000 Ib 0.00
0.00 Iblhr TPY**'1""":'1,·"'!"~'~oro:"'!o'~~"':!:"'~"!!'t"~iP""'i!;"'~~"!":'~~~'~"'r··,!'tli'~,~,~'?'1~~_1oI"'_"""!o ~~~"""""~I'I""'1I'!'ol"""**  __t'OI\"_

# • 

# • • • Oakota-3 E&P Company, LLC
WolfChief 27·34H Pad Associated Wells: Wolf Chief27·34HD. 27-34HZ. 27-34HC,27·34HX. 27-34HW, 27-34HA 

### Casing Head Gas
502 Created byCombustion (PTE): wt% Control % $021 - 5.779 scf/hr x 111379 sefnb-mole x 129.64686 Ibllb-mole 

### 1 x 0.00%1 x 1 98% 1 0.00 IblhrJ
0.00 Ib/hr x 8760 hrfyr x 

# '1 ton/2000 Ib -­ 

### 1 0.00 TPY 1 502 Created byCombustion (Actual): $02

### 1**5-;7i9-~:J** x 11/379 scfllb-mole x
0.00 129.64686 Ibllb-moIe 

### I
Ib/hr x x
8760 hr/yr wt% Control % 0.00%1 x 1 98% 

## I

x 

# '1 ton/2OO0 Ib 0.00
0.00 Ib/hr

### J
TPY 1 CO Created byCombustion (PTE): CO:I 5,779-dr x I 1.700 Btu/set I x 1 Mmbtull,OOO,OOOBlu X 0.370 IblMMBtu -, 3.64 Iblhr 1- 3.li4lliihr - I x 8760 hrfyrJ x 1 ton/2000 Ib J 15.93 TPY CO Created by Combustion (Actual): 

### cO:1 5;179 set/hr x 

### 1 1,700 Btu/set 

### I x 1 Mmbtul1,OOO,OOO Btu )( 0.3701b1MMBtu , 3.64 Ib/hr
:U4lblhr x- 8700nrlYr­ 

### d x ,-nOilI200016 15.93 TPY-­ ,

# • 

# • •

Wolf Chief27-34H Pad Associated Wells: Wolf Chief27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 

# C CaSiOgHead GaS -----­**~---- ---~-**  

# •

Dakota-3 E&P Company, LLC

PM Created by Combustion (PTE): PM:I 5,n9 scflhr x I 7.6 IbI1,OOO.OOO scf
0.04 Iblhr x 8760**hr~** 0.04

x Iblhr
1tonl2000 Ib 0.19 TPY PM Created by Combustion (Actual): PM:I 5,779 scflhr 

### )( I 7.6 Ibl1.000.000 set 0.04 Iblhr
0.04 Iblhr 

### J )( 

### L 8760 hrM:::::J x 1IOnl2OO0 Ib 0.19 TPY "NOx.502. 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).

"'i",
..**,,,*,,",,,,.lr~""""'","~~W:'I'\"',~~,'.~,,,:-r;,/"_,,,** ..."/
..**,,,,W'~.~,_** ..**::r,,,~:I'** .....,..""""'\

__**'·.*'~"''''_'~:'\'"'~~,~~,~'',~****,~** M 4 "'**~** £#**1,:.'~"""'~_~**

# • • r Dakota-3 E&P Company, LLC
Wolf Chief27·34H Pad Associated Wells: Wolf Chief27-34HO, 27·34HZ, 27·34HC, 27-34HX, 27·34HW. 27·34HA 

### Casing Head Gas

C02 (PTE): C02 Entrained in the Produced Gas: Control % C02:! -5;779

- Sdlhr 

### J )( 11/379 scfllb-mole x I 29.64686 Ibllb-mole 1 x 0.86%! x 

### I 98% 

### I 3.90 Iblhr 3.90 Iblhr x 8760 hr/yf x IlIonl2OOO Ib 

## J 17.08 TPY 

### 1 C02 Created by Combustion: C02:1 5,779­ SCflhr 

### 1 x 1120,000.0 IbI1.000.000 scf 

### d 893.52 Iblhr 

## :J I 693.52 Ib/hr x 8760 hffyr x 1tonl2000 Ib J 3037.64 TPY 

## :J Tolal CO2 Emitted (PTE):! 3054.72 TPY 

### REGULATED GREENHOUSE GAS EMISSIONSb



# .r 

# •

# • 

# • • •

Oakota-3 E&P Company, LLC

C02 (Actual): C02 Entrained in the Produced Gas: wt% Control % c02:1--U19--SClF] x '11319 scfnb:rrioie-, x 129.64686 11i11ii=iI'IOie 1 x 0.86%1 x 1 98% 1 3.90 Iblhr 3.90 Iblhr x 

## r ---s760 hr,yr- I x '1 tonl2OOO Ib - 

## r 17.08TPY I C02 Created by Combustion: c02:1 -5,119 scOiir x 1120;000:0 11i/1,OOO,OOO SCI C69 3.52ibihCJ 693.52 Ib/hr x 8760 hrlyr x C7t0n72000lli

### :J [3037.64 TPV Total C02Emitted (A1lowable):1 3054.72 TPY**"~~'"",!1<Y'''\'''''''~>1O'-'''''~~'''~~~M';+'''.'''''''''''''':''1'l'''!'<"'''''~.''~!.'/'''!'''~'''****'.~i!""'I1"~\'''''~'''''''~"''~-'''*f'"****l(_,"'~~~i~** WolfChief27-34H Pad Associated Wells: Wolf Chief27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27·34HW. 27-34HA 

### Casing Head Gas

Controlled CH4 (PTE):
CH4:1 5,779 scflhr x 111319 scfnb-mole x 129.64686 Ibllb-mole 1 2.33 Iblhr x x 8760 hr/X!: wt".4 Control % 25.75%1 x 1 98% 

## I

x 11 tonl2000 Ib 2.33 10.20 Iblhr
TPY
Controlled CH4 (Actual): CH4:! 5,779 scflhr x 111379 scfnb-mole x 

### I 29.64686 Ibnb-mole 

### I**2.33~r:::::J** x x 8760**hr~** wt% Control % 25.75%1 x 1 98% 

## I

x 11 tonl2OO0 Ib 2.33 10.20 Iblhr TPY

'!((

# • 

# • • • Oakota-3 E&P Company, LLC



# . C02 and N20 emission factors are from AP-42 Table 1.+2 (Emission Factors for Natural Gas Combustion)
. Wolf Chief27-34H Pad Associated Wells: Wolf Chief27-34HD. 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 

### Casing Head Gas
N20 Created by Combustion (PTE):
N20:1 5,779 scflhr 

### I J( 

### I 2.2 Ibl1.000.000 set 

## I 1.27E-02 Iblhr 

## I J( 

## I I = 8760 hr!f !1.27E-02 IbII1r 

### I 

## I J( 

## I 1 10012000 Ib 

## I = 

## I 3.18E-03 TPY 

## I N20 Created by Combustion (Actual):
N20:1 5,779 scflhr 

## I x 

## I 2.2 Ib/l.000.000 scf 

## I = 11.27E-02 IbII1r 

## I I 1.27E-02 IbII1r 

## I x 

## I 8760**hr/~** 

## I x 

## I 1 tonl2OOO Ib 

## I = 

## I 3.18E-03 TPY 

## I__ 

# • 

# • 

# • • I Dakota-3 E&P Company, LLC 

# I

WolfChief 27-34H Pad Associated Wells: Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 

## HeaterTreater Burners

Burner Rating I 4,500,000 Btulhr IThls burner rating reflects the combined size ofall ofthe proposed heater treatsr burners at the facility.

Nox: I--O:-fO-ltllMMBtU:J x 4.50 MMBtulhr I 

### = I OM1 IIlthr -) 

## rOAm Ib7lif::J x 8,760 hrfyr I x 111007200016 I**n:9~iP'(** co:! 0.08 IliIMMBiU x 4.50 MMBtulhr I ,---0.31-1**-Iblh~r ~**  (f.37 IbJhr - I x Ca-;f60 hr7Yf x ,lionj 2000 ItlI 

## r 1.623 illY S02:!5.88E..()4 ffi7MMl3l.i.i x r4:5<lmBtUlhrI [ 0:003 lIi7hr -) G6SE-03 Ibfhr· ::J x 8,760 hriyrJ x .1tooT2000Tb I 0.012 TPYPM:, O.OT IbJMMBtu x 4.50 MMBtufhr ,**D~lb7firJ D·or-jbl~**  

## J x 8.760 hriyr x 11 ton f2000 Ib 

### I 

# em' -rpy-]**'''~'~''0'~'''~'''~-:'''''''>~Y'l'l"''")9'".''''P'':"~''f''i'·::;''''''¥.'"'_~'~_'_P'_, """"-"~~_;I'\"'~~_~.ol'~'f't_~""''''I'!'~~J~'''''** **',"",~_'''''''''''''~!!i'<''~'''~>~~~**

# • 

# • 

# • • Dakota-3 E&P Com

Wolf Chief 27-34H Pad Associated Wells: Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 

## II Heater Treater Burner a

# ~ voc:1 0.01 IblMMBtu x 4.50 MMBtulhr 

## I 

## = 0.024 Iblllr 0.02 Iblllr x 8,700 hr!f x 

### 11 ton f2000IbI 

## = 0.106 rpv

HAP:

## 1 0.002 IbfMMBtu x 4.50 MMBlufhr I = 0.008 Iblhr la.34E-D3 Ibfhr x a,760**hr~** x 

# 11 too f2000 Ib 

## I 0.037 rpv

C021117.647 IbfMMBtu x 4.50 MMBtulhr

## I = 

# 1 55.412 Ibfhr 1]@li§.+02 Ibfhr
_ 

### I x a,76l) hrlyr .1 x 

### 11 too f2000Ib1 

## = 12,318.824 

### Tpy
_

# • 

# • • 

# • I Dakota-3 E&P**ComE!an~,** 

# LLC 

# I

Wolf Chief27-34H Pad Associated Wells: Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 

## Heater Treater Burnera

CH4:1 0.007 IblMMBtu x 4.50 MMBtulhr

### I 0.030 Iblhr 

### ffi!8E-02 Iblhr:::J 8,760 hrlyr 

### I x 

# '1 ton f2000 Ib 

### I 0.130 TPY )(
N20:, 0.001 Ib/MMBtu x 4.50 MMBtUlhf] I 0.006 Iblhr
.. (S.95E=03l67fif::J x 8,760 hr¥ x I 1 ton f2000 Ib 

### I 

### = COJ11&fPY-­ "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-1 of Subpart W). "U3 NOxTPY C---u2---coT 

### Pv

### :J r-o:Jll-s02f1>y:J**C:~F)t..ffpy** 0:11 VOC TPY 0.04 HAPTPY [23'18:82 C(j2TPY:J CI[f3·CH4TPY 0.03 N20TPY**·"-·~""i'\if"-""r<:0·"""",'J&'~of')'_~'N'!!"'''~V'''?'~J'''''~,''~->'** • .,;,.".,...,
..**'''r'~~""M!Q/'-."** __ '1't'

__**",,_.,""'~~"~m** __**,,l""~** __**~'1'._,_''''''**

# • 

# • 

# • •**~** 

# . Dakota-3 E&P Company, LLC II

Wolf Chief 27-34H Pad Associated Wells: Wolf Chief 27-34HD, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 

# II· Truck Loadout Emission

# Calculation-~ Saturation Vapor Molecular Temp + Load Loss Factor (5) Pressure(P) Welght (MW) 460 Ib/1000 gal 12.46 

### I x 

# I 0.60 

# I x 

### I 2.30 

### J x 

### I 42.14 

### I I 

# I 510.00 

# I 

# = I 1.42

LL Truck Load Load Time Total Gas Ib/1,000 gal Rate bbllhr hrs gal/bbl Emissions Ib/hr 1.42 

### I x 

## I 180.00 

## I I 

## I 1.00 42.00 10.74 

## I x 

## I I

# =I 1 LL Annual Emissions Uncontrolled 1b/1,000 gal bbl/yr gallbbl Ib/ton TPY C3+ VOC tpy 1.42 

## J x 

## I 728331.84 

## 1x 

## I 42.00 

## I I 

## I 2000.00 

# I 

# =I 21.72 

# I I 16.08 VOC Emissions Uncontrolled Control % TPY 16.08 

### I 

# I 100% 

# I I 0.00 

# .1 I _ Q.O«L ] 

# ====

# • 

# • • 

# •

=-== LL Annual Emissions Uncontrolled Ibl1,000 gal bbllyr sallbbl Iblton TPY 1.42 

### I 

### x I 728331.84 

### I 

### x 

# I 42.00 

# I I 

# I 2000.00 

# I = 

# I 21.72 

# I 0.23 '

# ~ HAPs Emissions I Uncontrolled Control % TPY 0.23 

### I 100% 0.00 0.00 

# I 

# I I 1 I 1 LL Annual Emissions Uncontrolled Ibl1,000 gal bbVyr**~allbb'** Iblton TPY C02tpy 1.42 

### I 

### x 

## I 728331.84 

### I 

### x 

# I 42.00 

# I I 

# I 2000.00 

# I =

# I 21.72 

# I I 0.06 CO2 Emissions Uncontrolled Control % TPY 0.06 100% 0.00 0.00 

### I 

# 1 

# I I 

# I I 

# I LL Annual Emissions Uncontrolled Ibl1 ,000 gal bbllyr sallbbl Iblton TPY CH4tpy 1.42 

### I 

### x 

# I728331.84 

# 1 x 

# I 42.00 

# I I 

# I 2000.00 

# I =

# I 21.72 

### I 0.43 

# 1 CH4 Emissions Uncontrolled Control % TPY 0.43 

### I I 100% 

### J J 0.00 

### I I 0.00 

### I

# • 

# • 

# II I Oakota-3 E&P Company, LLC 

# I I 

# I RICE Input Data

Combined Diesel Engines Hours ofOperation Maximum HP**Rati~** NOxg/hp-hr CO**g/h~hr** S02 glhp-hr PM g/hp-hr [VOC g/hp-hr HAP g/bh-hr C02g bh-hr CH4 gbh-hr N20 g/hp-hr



# • 87S0 1650 1.49E+00 2.61E+OO 4.S2E-06 4.8SE-OS 1.42E-01 1.02E-OS 2.54E-03 2.10E-02 4.20E-03



# • Description Engine" a.umedto operate ',760houra peryaar.**~nufactuflr** GUlrantee (40 CFR 13 Subpart"requirements),
...Altlc:hmentF ManufacturerGulrantee (40 CFR 13 SubpartIIIrequlrementt}, I
.. AftllchmentF**~P-42**Table 3.3-1 "P-42Tlble 3.3·1 ManufactuflrGuarantee (40 CFR 13 SubpartIHIrequirements), 1MAftllchmentF AP-42 Table 3.3-1**~P-42**Tlble 3.3·1 

### i«I CFR98 SubpartC, Table Co2 40 CFR98 SubpartC,Table Co2 Recycle Pump Description Hours ofOperation 8760 Enlline " I.umedto operate 8,760 houra paryor. Maximum HP Rating 48 Manufacturer'. maximum hp rating.**NOx~hr** 4.99E+OO**~2** Tlble 3.3-1 CO g/hp-hr 3.1SE+OO AP-42 Tibia3.3-1 502 g/hp-hr 2.68E-01**~2T.bIe** 3.3-1 PM g/hp-hr 3.27E-01 

### IAP-42Tibia3.3-1 rvOC glhp-hr 9.80E+OO 1AP-42Tabla3.3·1 HAP g/hp-hr 2.20E-01**~P-42** Table 3.3·1 C02 glbh-hr 4.90E+02 AP-42 Table 3.3-1 CH4 g/hp-hr 2.10E-02 

### leoCFR98 SubpartC,TibiaC·2 N20 g/hp-hr 4.20E-03 

### i«I CFR98 SubplrtC,Table (;,2

# • 

# •

[ Dakota-3 E&P Company, LLC 

# .. •

Wolf Chief 27-34H Pad Associated Wells: Wolf Chief27-34HD, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 

### [ Reciprocating Engine EmisSions - - - - - - - - ­
!;NGINE #1 1650 

### I MAX HP HOx; 1.49E+OO IlIHP

-HR I x 1650 HP x 111b 1453.6Ilrams 

## I S.43E+OO Iblhr x 8760**hr~** x 1ton 12000lb

## I " 2.38E+01 NOx TPY £Q;, 2_61E+OO IlIHP-HRI x 1650 HP x 11 Ib 1453.6srams 

## I 9.50E+OO Iblhr x 8760**hr~** x 1 ton 12000lb

## I '" 4.16E+01 CO TPY S02: U2E..­ !l!!:!P-HRI x 1650 HP x 11 Ib I 453.6 l!rams 

### I 1.84E..oS Iblhr x 8760**hr~** x 1ton 120001bl 7.20E-05 S02 TPY fAt USE..­ !l!!:!P-HRI x 1650 HP x 11 Ib I 453.6 Ilrams 1.76E..oS Iblhr x 8760**hr~** x 1ton 120001bl 7.73E-05 PM TPY**~** 1.42E..o1 !l!!:!P-HRI x 1650 HP x 

### 11 Ib I 453.6 llrams S.16E..o1 Iblhr x 6760**hr/~** x 1ton 12000lbI 2.26E+OO VOC TPY**~** 1.02E..oa !l!!:!p-HRI x 1650 HP x 11 Ib I 453.S !!rams 3.71E..o8 Iblhr x 6760**hr~** x 1ton 12000lbl 1.63E-05 HCHO TPY**~** 2.54E..o3 IlIHP

HRI x 1650IHP x 11 Ib I 453.6 l!rams 9.22E..03 Iblhr x 8760**h~** x 1 ton I 20001b

## I 4.04E-02 CO2 CH4: 2.10E..o2 !l!!:!P-HRI x 1650 HP x 

### 11 Ib 1453.6 !!rams 7.84E..o2 Iblhr x 8760**h~** x 1 ton 12000lb

## I 3.35E-01 CH4 H2O: 4.20E..o3 glHP-HRj x 1850 HP x '1 Ib 1453.6grams 1.S3E..o2 Iblhr x 8760 hr/yr x 1 ton 12000lbj 6.69E-02 N20

# • 

# • • 

# • Dakota-3 E&P Company, LLC
Wolf Chief 27-34H Pad Associated Wells: Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 

### [ Reciprocating Engine Emissions
ENGINE

### #2 ,--.a::JMAXHP Hax: 

### I U9E+OO gIHP-HR! x 48 HP x 11tb/453.6gramsl x 0.53 tblhr x 

### I 8760 hrlyr x 11ton/2000lbl = 12.31E+OO NOXTPY:J**~** 13.18E+00 glHP-HRI x 48 HP x !1lb/453.6gramsl x 

### I 0.33 Iblhr x 

### I 8760 hrlyr x 11 ton I2000lb I 

### = 11.46E+OO COTPY I 2.88E.o1 glHP-HRI x 48 HP x 111b 1453.6 grams 

### I" 2.84E.o2 Iblhr x 

### I 8760 hr/y! x 11 ton 12000lbl 

### = I 1.24E-01 S02 TPY fM.i. 3.27E-01----g?HP:tiRI x 48 HP x 11 Ib 1453.6grams I I 3.48E.o2 Iblhr x I 8760 hrlyr x 11 ton 12000IbI = I 1.52E-01 PM TPY :J VQC: I 9.80E+OO gtHP-HRI x 48 HP x 11 Ib 1453.6 grams I x I 1.04 Iblhr x I 8760 hr/y! x 11 Ion 12000lbI = I 4.54E+OO VOC TPY I 2.20E..o1 gtHP=HR] x4rHO x 11tb1453.6 grams I 0.02 Iblhr x 

### I 8760 hr/y! x 

### 11 ton 12000Ibl = 

### I 1.02E-01 HAP TPY &Qi;: 

### I 4.90E+02 g/Hp-HRI x 48 HP x 111b 1453.6 grams 

### I
.. I S.18E+01 Iblhr x 

### I 8760 hr/yr x 1110n 12000lbl = I 2.27E+02 C02 fPY CH4: 

## r 2.10E.o2 gtHP-HRI x 48 HP x 11 Ib 1453.6 giiiliS] 2.22E.o3 Iblhr x I 8760 hr/yr x 11 ton 12000lbl = I 9.73E-03 CH4 fpy !!mi. I 4.20E..o3 g!Hp=HRI x 48 HP x 11 Ib 1453.6grams I , 4.441:-04 Iblhr x 

### I 8760 hr/yr x '1 Ion 12000lb, .. , 1.95E-03 N20 TPY

# • 

# • • 

# •

Wolf Chief 27-34H Pad Associated Wells: Wolf Chief27-34HD, 27-34HZ. 27-34HC. 27-34HX, 27-34HW. 27-34HA 

# Oakota-3 E&P Company, LLC

Reciprocating Engine Emissions- - - - - - - - - - 

# -I

TOTALS 

### I 2.61E+01 

### I 4.31E+01 

### I 1.24E.o1 

### I 1.52E.o1 

### J6.80E+OO

1.02E.o1 2.27E+02 3.44E.o1 6.89E.o2 NOxTPY 

### co TPY S02TPY PM TPY VOC TPY HAPTPY C02TPY CH4 TPY H20 TPY ---­**"~ ,~** **,.~** __**n'O>~"** __**'~_'''''''''** ., __.".,
.. __ ••

____ __'''''<_'_'

__-'_'''
_ __""

____**...,.,._,~~I'I,,,~,..,.,~""** .., __

# •
ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS

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

# •

•

Dakola-3 Eap Company. LLC. NSR Synthetic MinorApplication WEP211324 

# •

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

### * Pro;ect setup Information 

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

### project File : y:\projects\williams 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 51.00Cps i 

### g]**sep~rator** 

### Temperature 82.50[FJ Amblent Pressure 14.70[psia] Ambient Temperature 70.00[F] CI0+ SG 0.8000 CI0+ MW 235.14 Low Pressure oil

---------------------------------------------------------------------­ NO. Component wt % 1 H2S 0.0014 2 02 0.0000 3 co2 0.0042 4 N2 0.0015 5 Cl 0.0320 6 C2 0.3654 7 c3 1.2089 8 i -C4 O. 

### 3443 9 n-C4 1.5191 10 i-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 CI0+ 53.7971 17 Benzene 0.0479 18 Toluene 0.0997 19 E-Benzene 0.0600 20 xylenes 0.3998 21 n-C6 1.4864 22 224Trimethylp 0.3663

.. Sales oil

----------------------------------------------------------------------------­ production Rate 1000[bbl/day] Days of Annual operation 365 [days/year] API Gravity 41.85 Reid vapor pressure 5.90[psia] ****************************************************************************************** 

### * calculation Results 

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



### -- Emission Summary

---------------------------------------------------------------------­ Item uncontrolled uncontrolled [ton/yr] [1

### b/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 SOPO wt% uncontrolled Recovery Info. Vapor 40.2300 [MSCFO] HC Vapor 40.0300 [MSCFO] 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 C02 2.160 0.493 4 N2 0.786 0.179 5 C1 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 ;-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 wt % wt % wt % . wt % wt % wt % 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 CO2 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 C1 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 ;-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 C10+ 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/Ai r] 1.35 1.50 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 2Oil Storage Tank 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,Q 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 (bbllday) (P) 0 50 100 300 1000 Emission (tons/yr) 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

.....-Total HAPs _VOCs,C3+

- Linear (Total HAPs)

- Linear (VOCs, C3+)

bbl/day 

# • 700 600



# ... 500 II 400

# ~ 300 c 0 200 

# - 100 0 0 500 1000 1500



# •

# •
ATTACHMENT D: REPRESENTATIVE LOW PRESSURE OIL ANALYTICAL DATA



# •



# •

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

# •

# •

•



# •

• Laboratory • uas Measurement Emissions Testing • Sample Collection :A2LA Accredited • I'<4[;LAP Ilu:n:dlted • CPA Ccrtlfled 19 Country Acres Rd. Rlv.,rton. \flY 81M)) • Tollf'n:." (866) 985-0866 • £-m
..n, Info(ii
....,dslon-ubs.c:om • Online: www.Predslon.t.a
.....cOlll


### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY Company
.................... ZENERGY Lab Number
................ CR-I0330 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 % Uq. 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 Com£onents 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 a-Xylene 0.116 0.087 0.074 

# •

API GRAVITY AT 60/60 F, calculated
........................................................................ 60.3 SPECIFIC GRAVITY AT 60/60 F. calculated
............................................................ .. 0.7378 RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION
.............................. . 0.7958 AVERAGE MOLECULAR WEIGHT
.......................................................................... 140.803 AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION
......................... . 228.881 TRUE VAPOR PRESSURE AT 100 F. PSIA, calculated
............................................... . 33.400 AVERAGE BOILING POINT, F
................................................................................. 299.063 CUBIC FEET OF GAS I GALLON OF LIQUID. as Ideal Gas
......................................... . 19.106 BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated
............................................... .. 122456.887 LBS I GALLON OF LIQUID. calculated
...................................................................... 6.152
'\( n', J I<)"., 'ILL ( ALU. LATH lNS PERFORJ\IEO lSI:,(, PHYSIC '\.1 COl\:q\N**r~** rROi\1 GP".**214~** 09. l'Hl-. J'\.BU·" (IF PHYSIC '\.1. CONSTANTS FOR HYDR()(\RB(lNS "."10 (lTHLR « )\!P(llNDS (IF lNTf-.RFSJ f() 1'1 IE )\\TI RAJ C;,'\.S l!\OlSTR, 

# •

•

# • EXTENDED HYDROCARBON LIQUID STUDIES 

### CERTIFIC\TE ()[. ANAL\'SlS Company
.............. .. PRECISION ANALYSIS LabNumber
............ . CR-10330 StudyNumber
........... . CR-2B Date Sampled
........... .. 7-15-2010 DateTested
............ .. 7-22-2010 Sample Identification
............... . ZENERGV CROSS 2-13 H CRUDE OIL Sample Location
....... .. 

### MONTANA. 

# • Sample Pressure
......... . 

### N/A SampleTemperature
.... 

### N/A Flowrate
................. .. 

### N/A County
.................... . 

### DUNN I-QUART TestMethod
............ .. 

### VARIOUS Sample Container
........ BOTTLE TEST PERFORMED API GRAVITYAT60/60 F (ASTM D-287), observed
..................... . SPECIFIC GRAVITYAT 60/60 F (ASTM D-1657), calculated
........ .. REIDVAPOR PRESSURE (ASTM D-323), PSIGAT 100 F
.............. TOTALSULFUR CONTENT (ASTM D-5453), PPMW
................ .. TRUEVAPOR PRESSURE (ASTM D-2889), PSIA AT 100 F
........... BASIC SEDIMENTAND WATER CONTENT, % BY VOLUME
.... COPPERSTRIPCORROSION (ASTM D-130), 1HOURAT 100 F
........... FREEWATER, observed
........................................................ . 

# • RESULTS
42.5 0.8132 5.2 PSIG 658.98 PPMW

N/A N/A N/A N/A

NOTATION' ALL TESTING PROVIDEDABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY OUTLINED BY THE AMERICAN SOCIEn' FOR TESTING AND MATER1A1.S (ASTM)
.



# •LaboralO!), , Gas I'lcuuranull [mluiuru Tullng • Sa...,..., CoIiec.liGn 

# •

Chromatogram Cross 2-l3H C:\GCsolution\DRO\DRO Data\08-201O\08-01-2010\Cross 2-13H.gcd

- Channell

3 :;' (I 100000 200000 250000

2.6671**=~:>..ilLJ-----3.6321 ~·-~-------------------------------4.%91**  ====;..5..5il8L
_______ ___ 5.608lDecane (Cl0)**-:-----~~------------7.0831** ==::::"[6331---------8.4521 ;;::;-;:-:--------------9.7241**~FF"~------------** 10.9111**------~---12.031!** -------13.088 ! _'1"zII'rt---14,089! rncn--15.0411 15.947 ! o-Ietphenyl Intensity



# •



# •

•

# •

•



# •

• Company
.................... Lab Number
................ Date Sampled
.............. Sample Identification
.................... Laboratory • Gas Measurement Emissions Testing • Sample Collection A2LA**~c(.;redJted** • !'ICtAl"**~(.cn.:dlted** • EPA Certified 29 Counlry Acres Rd. RI""rton. 1o\'Y 82501 • Toll Frec. (866) 985.0866 • 1.-
.....11: Info0Freclslon-Labs.com • Onlln"" www......c:bfon-La
....co... 

### EXTENDED HYDROCARBON (GLYCALC) UQUID STUDY Study Number
.......... CR-3 Date Tested
............. 7-23·2010 PATRICIA CHARGING 4-15 HCRUDE Oil Sample Location
.......... Sample Pressure
......... Type Sample
............... Test method
................ Hydrogen Sulfide
.......... Oxygen
...................... Carbon Dioxide
............ Nitrogen
..................... Methane
..................... Ethane
....................... Propane
..................... iso-Butane
.................. n-Butane
.................... iso-Pentane
................ n-Pentane
................... Hexanes
..................... Heptanes
.................... Octanes
..................... Nonanes
..................... Decanes+
................... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... n-Hexane
.................... 2,2,4·Trimethylpentane
... TOTALS
..................... ZENERGY CR-10330 7-15-2010

MONTANA. 80 PSIG SPOT GPA·2286 Components Mole % 0.008 0.000 0.014 0.008 0.398 1.921 3.914 0.862 3.606 1.238 2.329 2.180 8.849 21.103 15.296 34.917 0.085 0.148 0.060 0.473 2.204 0.387 100.000 Sample Temperature
.... County
...................... Sampling Method
........ 70 F DUNN yz PISTON Weight % 0.002 Liq. Vol. % 0.002 0.000 0.000 0.004 0.004 0.001 0.001 0.043 0.107 0.387 0.811 1.155 1.702 0.335 0.445 1.403 1.795 0.598 0.715 1.125 1.333 1.257 1.415 5.934 6.445 16.133 17.068 13.130 13.589 56.412 52.378 0.044 0.038 0.091 0.078 0.043 0.037 0.336 0.290 1.271 1.431 0.296 0.317 100.000 100.000

# •

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 GRAVITY AT 60/60 F, calculated
....................................................................... . 57.8 SPECIFIC GRAVITY AT 60/60 F. calculated
.............................................................. 0.7475 RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION
............................. .. 0.8050 AVERAGE MOLECULAR WEIGHT
.......................................................................... 149.417 AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION
.......................... 241.399 TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated
............................................... . 46.319 AVERAGE BOILING POINT, F
................................................................................. 314.836 CUBIC FEET OF GAS I GALLON OF LIQUID. as Ideal Gas
......................................... . 18.857 BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated
................................................. 122700.693 LBS I GALLON OF LIQUID. calculated
...................................................................... 6.232

,()')\TI( l" '.II**(A!(tL\Tl(),,\~ PERF(lR~IE[)**  ISI1'.G PHYSIC**~I** (O"-,S1 \,,\E FRu,1 CP\ 214; 09. nu" nBLES 01'**PHY~I(** .\1.**C(j"~T** \!':TS FOR H'I1)RO( \RB( l,\S \,\1) ( lTHER U lMPUI",ns 01 !};TI-.RESl 

# •

•

# • EXTENDED HYDROCARBON LIQUID STUDIES 

### CERTIFlC,\TF ( H**.\~,\LYSIS** Company
............... . ZENERGY Lab Number
............ . CR·I0330 Study Number
.......... .. CR-3B Date Sampled
........... .. 7-15-2010 Date Tested
.............. 7-22·2010 Sample Identification......•...•..•.. PATRICIA CHARGING 4-15 H CRUDE OIL Sample Location
........ . MONTANA. 

# • Sample Pressure
......... . N/A Sample Temperature•... N/A Flowrate....•.........••... N/A County
.................... . DUNN I-QUART Test Method
.............. VARIOUS Sample Container
........ BOTI1.E TEST PERFORMED API GRAVITYAT 60/60 F (ASTM D-287), observed
.................... .. SPECIFIC GRAVITYAT60/60F (ASTM D-1657), calculated
........ .. REIDVAPOR PRESSURE (ASTM D-323), PSIG AT 100 F
............ .. TOTAL SULFURCONTENT (ASTM D-5453), PPMW
................. . TRUE VAPOR PRESSURE (ASTM D.2889), PSIAAT 100 F
.......... . BASIC SEDIMENTANDWATER CONTENT, % BYVOLUME
.... COPPERSTRIPCORROSION (ASTM D-130), 1HOURAT 100 F
........... FREEWATER, observed
........................................................ . 

# • NOTATION RESULTS 41.2 0.8193 6.6 PSIG 940.25 PPMW

N/A N/A N/A N/A

AU TESTING PROVIDEDABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY OLTLINED BY THE AMERICAN SOCIETI FOR TESTING

### A.'·m MATERIALS (ASTM)



# •u.....--3.6351

-------5.9491 ----------------7_0841 

### =====rni4T------- 8A53 1

"...,.....---------- 9_7251 ;,;.;,....:..;,.--------10.9131

-------­ ------13.0881 -_H1I1H--14.0911

15.950 Io-tetphenyl laboralof) , (;;as l'tu.wrcmtl1l [ml.jOlon! 1"",lIl1g • Samplt**CoU~lIofl** 

# •

Chromatogram PC 4-15 1-100 C:\GCsolution\DRO\DRO Data\08-2010\08-01-2010\PC 4-15 HOO.gcd

- Channell 

## o 50000 100000 150000 200000 250000**O.CH---L--'~-'-~"--'----'-L---_~~--'-~---'---'------'--~-'---L~---~--'-----'-"'--** __-'1_'----"-, Intensity

2-6671**----------~------4_0701**
=;.;>..:WJ..!.....------

_______ 5.610 1Decane (C10) 

# •

12.0311



# •

5' 

# • 3

# •

ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS



# •

•

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

# •

# • • •

Averaae Mandaree Area Gas Compositional Data CO2 (Wt'JlI 44.010 1.161 0.836 0.n4 0.87 0.893 0.873 0.681 0.863 1NIIrot"n IWt"I 28.013 3.626 2.541 1.414 1.352 3.545 3.471 0.471 HlS (Mol""! 34.081

0 0 0 0 0 a 0 C1 IWt"I 16.043 36.543 33.17 20.353 19.208 25.407 32.094 13.456 C2 IWt"I 30.069 24.689 23.484 26.461 21.796 22.578 16.795 30.949 C3 (Wt'JlI 44.096 18.317 18.569 28.74 27.321 25.451 17.765 33.204 2.346 1 0.000 1 25.747 1 23.822 1 24.19S 1 1.(4 (Wt'JlI 58.122 1.949 2.543 3.763 4.559 3.399 3.156 3.787 n.(4 IWt'JlI 58.122 5.713 7.S23 10.995 14.169 11.195 11.786 11.001 3.308 1 10.340 1 Note: All calculations were pr.formed by PrecisionAnalysis using physical constants from GPA-2145-09. 1,(5 

# 1-' 72.149 1.092 2.219 1.776 2.623 2.037 2.666 1.714 2.018 

### Collected 1011112011 n-CS IWt"I 72.149 1.759 3.884 2.491 3.749 2.674 3.871 2.273 2.957 C6 I-I 86.180 1.627 2.219 1.15a 1.845 0.515 2.76 0.941 1.5S1 C7 I-I 101.21 1.321 1.481 0.773 1.209 0.789 2.453 0.252 1.183 1 ClI+ IWt"I 114.23 0.545 0.166 0.498 0.121 0.487 0.109 0.605 0.362 _" Toluene 

## (WI", 92.140 0.264 0.11 0.216 0.097 0.137 0.215 0.19 0.176 (
....n...n.. IWI'" 106.170 0.014 0.006 0.014 0.007 0.016 0.01 0.011 0.011 

# •

Xylenes IWt"I 106.160 0.462 0.026 0.05 0.021 0.066 0.038 0.049 0.102 

# n-tIe.... (_I 86.180 0.657 1.138 0.536 0.975 0.771 1.405 0.375 0.837 

# 1---1·pemK

# I A".**me~** 

## II..... Gr ••1ty Mo"'cuia (8tu'ocll eo_lOll W
....t 1462.236 0.8862 25.666 1558.1 0.9345 27.065 1796.8 1.0738 31.101 1874.17 1.1253 32.591 1663.5 1.0141 29.37 1602.8 0.9765 28.281 1945.1 1.1551 33.454 Aver,ages 

### I (Wt'JI) 78.112 0.257 0.085 0.038 0.075 0.04 0.53 0.043 0.153 pentane 114.230 0.004

0 0 0.002

0 0.002

0 0.001 11700.3871 1.024 129.64686

",',',. _)·"",t',,, "'"
..**""~:,"'r'""''''''~""<">"~"""<",·"""~~~** __**""~":",,~,,,,,,,,-,,-,,,,,,,,,,,,, """"",~,?~,'~1\''''''"''(_~''''_'**  ____**'r''''~,q''''4''*''''_~'~1'''''~~'''J1:''''''''''''C,'''''''I''_"C~"~_lII.",",~,....-y"'~_'1,_l'f,""~t"I".**

# ..

29 Country Acre. Rd, RJyerton. WY 82501 ontlno, _.Proct.ton-Lllb•.com E_alb Infoll!Pr.cl.t..,....b•.com

# PRE~ Toll f'r_ ....mben (1158,**"1~18.**

## ~AN 

# SIS

Client: SISON ENGINEERING Analysis Date: 10/11/2011 Sample 10: AUSIA FOX 16-9 Date Sampled: 10/11/2011 Unique #: Purpose: 

# • Sample Temperature: 62 DEG F Sample Pressure: 20 PSI Sampled By: TC Type Sample: ONLINE County: DUNN
Components Carbon Dioxide.........•... Mole % 0.677 Weight 0/0 1.161 Liq. Vol. % 0.551 Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... 0.000 3.323 58.464 0.000 3.626 36.543 0.000 1.742 47.240 Ethane
........................ Propane
....................... iso-Butane
................... n-Butane
...................... 21.074 10.662 0.861 2.523 24.689 18.317

1.949 5.713 26.862 13.999

1.342 3.791 iso-Pentane
.................. 0.389 1.092 0.677 n-Pentane
.................... Cyclopentane
............... n·Hexane
..................... 0.599 0.028 0.196 1.684 0.075 0.657 1.035 0.039 0.384 Cyclohexane
................ Other Hexanes
............. 0.196 0.147 0.642 0.492 0.317 0.287 

# " Heptanes
..................... Methylcyclohexane
........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... 0.338 0.129 0.001 0.085 0.073 1.321 0.493 0.004 0.257 0.264 0.744 0.247 0.002 0.113 0.117 Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ 0.003 0.112 0.122 0.014 0.462 0.545 0.006 0.206 0.299 Totals
........................ 100.000 100.000 100.000


# •

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % Cydopentane Cyclohexane 2-Methylpentane 3-Methylpentane n-Hexane Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene 

# • Ethylbenzene m-Xylene p-Xylene o-Xylene 0.028 0.075 0.039 0.196 0.642 0.317 0.092 0.310 0.181 0.054 0.182 0.106 0.196 0.657 0.384 0.129 0.493 0.247 0.001 0.004 0.002 0.085 0.257 0.113 0.073 0.264 0.117 0.003 0.014 0.006 0.018 0.073 0.033 0.076 0.313 0.139 0.018 0.076 0.034

SPECIFIC GRAVITY@60/60 F. calculated
.................................................. . 0.8862 TOTALGPM (Ethane Inclusive)
............................................................... .. 10.561 CALCULATED BTU I REAL CF @ 14.73 PSIA, dry basis
................................ .. 1462.236 CALCULATED BTU I REALCF@14.73PSIA,wetbasis
................................. . 1437.527 AVERAGE MOLECULARWEIGHT
........................................................... . 25.666 MOLAR MASS RATIO
.. ,......................................................................... .. 0.8862 RELATIVE DENSITY ( G :II: Z (Air) I Z ). calculated
........................................ 0.8911 IDEAL GROSS HEATINGVALUE, BTU I IDEALCF @ 14.696 PSIA
................. . 1450.907 COMPRESSIBIUTYFACTOR (Z)
.............................................................. 0.99453
PROPANEGPM
................................................................................... .. 2.9297 BUTANEGPM
...................................................................................... . 1.0743 GASOUNE GPM (PENTANE AND HEAVIER)
......................................... .. 0.9357**~(n** \TI<II.I ( \I.U I.**\T1(l~S** PERrOR"IED I**~I:--('** PHY,I( II «**)',ST\~T~** I'R( )\1 (,1'\ 211i II') fHI I ".Ill.F, • Ilf PHYSIC \1 (O:-':ST,0:TS FOR HYDRo( \lUl()","**\~D()TH!)RC')\IP()I~[)S('I** L"-TLRL,'j n) rHF " \ n R,I!. G \5 I:-JDI ,TRy



# •

# •

29 Country Acres Rd, Riverton, WY 82501 Online: _.Preclslon-La.s.com E-mail: Infot\.Pr_lslon.Laba.com Toll Fro. Number. (888) 985.080

Client: BISON ENGINEERING Analysis Date: 10/11/2011 Sample 10: HIGH HAWK 4-9 Date Sampled: 10/11/2011 Unique#: Purpose: 

# • Sample Temperature: 59 DEG F Sample Pressure: 25 PSI Sampled By: TC Type Sample: ONLINE County: DUNN
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 Cyclopentane
............... 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 Methylcydohexane
........ 0.025 0.073 0.040 2,2,4-Trimethylpentane
... 0.000 0.000 0.000 Benzene
...................... 0.D18 0.043 0.021 Toluene
....................... 0.069 0.190 0.093 Ethylbenzene
............... 0.004 0.011 0.005 Xylenes
....................... 0.015 0.049 0.024 C8+ Heavies
................ 0.177 0.605 0.366 Totals
........................ 100.000 100.000 100.000


# •

# •

•

• ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % Cyclopentane Cyclohexane 2-Methylpentane 3-Methylpentane n-Hexane Methylcyclohexane 2,2.4-Trimethylpentane Benzene Toluene Ethylbenzene m-Xylene p-Xylene o-Xylene 0.037 0.079 0.045 0.047 0.119 0.065 0.183 0.471 0.303 0.108 0.278 0.179 0.146 0.375 0.242 0.025 0.073 0.040 0.000 0.000 0.000 0.018 0.043 0.021 0.069 0.190 0.093 0.004 0.011 0.005 0.002 0.008 0.004 0.010 0.033 0.016 0.003 0.008 0.004

SPECIFIC GRAVITY@ 60/60 F, calculated
................................................. .. 1.1551 TOTALGPM (Ethane Inclusive)
................................................................. 19.847 CALCULATED BTU I REAL CF @ 14.73 PSIA,. dry basis
................................ .. 1945.085 CALCULATED BTU I REAL CF@ 14.73 PSIA, wet basis
................................ .. 1911.926 AVERAGE MOLECULARWEIGHT
........................................................... . 33.454 MOLARMASS RATIO
............................................................................ .. 1.1551 RELATIVE DENSITY ( G x Z (Air) I Z ), calculated
........................................ 1.1668 IDEAL GROSS HEATINGVALUE, BTU I IDEALCF @ 14.696 PSIA
................ .. 1921.067 COMPRESSIBIUTYFACTOR (Z)
.............................................................. 0.98992
PROPANE GPM
..................................................................................... 6.9222 BUTANEGPM
...................................................................................... . 2.7025 GASOUNE GPM (PENTANE AND HEAVIER)
.......................................... . 1.0377 '«IT\TH)" IlJ (\!.u IlnO'SPfRH'R,IFDLSL,CI'HYSICli**U)";T\.'TSrR{)'!CP\21~'il\'.** [HI [\[ILlS (If' PH) ,I( II**C()~.sl ,"T~**  H lR HYDRO( .\RB( )", ,,'<D OTHFR u ),[POI "!l:; (Ie l'dfR[ ')T ro nil"Y[{ R.\' (, I' I"DL ,TR\



# •

# •

29 Countrll Acre, Rd, Riverton. WY 82501 Online. _.Precl.lon·Lab••com 

# PRECISION/7 E-mall.lnfoGlP.ecl.lon·Lab••com Toll Free Numb
.... (866) '85-G8&6

# ~SiS
Client: BISON ENGINEERING Analysis Date: 10/11/2011 WILLIAMS Sample 10: NATHAN HALE 3-18 Date Sampled: 10/11/2011 Unique": Purpose: 

# • Sample Temperature: 59 DEG F Sample Pressure: 15 PSI Sampled By: TC Type Sample: ONLINE County: 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
..................... Methylcyclohexane
........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xytenes
....................... (8+ Heavies
................ Totals
........................ 0.561 0.000 3.504 56.578 1S.797 11.394

1.536 5.735 1.045 1.419 0.102 0.461 0.304 0.333 0.692 0.242 0.001 0.192 0.066 0.003 0.010 0.027 100.000 Weight % 0.873 0.000 3.471 32.094 16.795 17.765 3.156 11.786 2.666 3.619 0.252 1.405 0.903 1.015 2.453 0.842 0.002 0.530 0.215 0.010 0.038 0.109 100.000 Liq. Vol. % 0.443 0.000 1.784 44.375 19.545 14.522

2.325 8.364 1.768 2.379 0.139 0.877 0.478 

# .. 0.634 1.478 0.451 0.001 0.248 0.102 0.005 0,018 0.064 100.000 

# •

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % Cyclopentane 0.102 0.252 0.139 Cyclohexane 0.304 0.903 0.478 2-Methylpentane 0.210 0.639 0.399 3-Methylpentane 0.123 0.376 0.235 

# • n-Hexane 0.461 1.405 0.877 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 m-Xylene 0.002 0.006 0.003 p-Xylene 0.007 0.026 0.012 o-Xylene 0.002 0.006 0.003

SPECIFICGRAVITY @60/60 F,calculated
.................................................. . 0.9765 TOTAL GPM (Ethane Inclusive)
............................................................... .. 11.511 CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis
.................................. 1602.761 CALCULATED BTU / REAL CF@14.73 PSIA, wet basis
................................ .. 1575.593 AVERAGE MOLECULARWEIGHT
.......................................................... .. 28.281 MOLARMASS RATIO
............................................................................. . 0.9765 RELATIVE DENSIlY ( G x Z (Air) / Z ),calculated
...................................... .. 0.9832 IDEALGROSS HEATING VALUE, BTU / IDEALCF @ 14.696 PSIA
................ .. 1588.143 COMPRESSIBIUlYFACTOR (Z)
.............................................................. 0.99316

PROPANE GPM
................................................................................... .. 3.1309 BUTANEGPM
..................................................................................... .. 2.3045 GASOUNE GPM (PENTANEANDMEA VIER)
.......................................... . 1.8621 

# • '" nnl<)'. 'ILl C'ILCUHH )'" PERH lR.\!ED L SI'.(; PHYSIC \1 , ().',:i·1 \;>-.. r.s FR( )\1 (;1'\ "·Ii ,,'J ['HI- I**\[JLr~** (Jr I'HYSJ( .\1**(()'.~1** v,:rs H)R HYDR')( \RU( '" -'1'-1) ()THI-R ( U\!l'()1 

## 'J), (n I:o..n- Rfsr fO fHE '- \TYR.\l C**\~** I0:Dl STRY



# •

# •

29 Country Ac:res Rd. Riverton, WY 82501 0"11"", _.Precl.lon
....b••com 

# PRECISION? E-mail: In.o(!IPreclalon·Lab••com Toll Free Number. (8&&) 985-08&&

# ~SYs
Client: BISON ENGINEERING Analysis Date: 10/11/2011 WILLIAMS Sample 10: SKUNK CREEK 1-12 Date Sampled: 10/11/2011 Unique If: Purpose: 

# • Sample Temperature: 78 DEG F Sample Pressure: 30PSJ Sampled By: TC Type Sample: ONLINE County: 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
..................... Methylcyclohexane
........ 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 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


# •

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. %



# • Cydopentane 0.070 0.167 0.092 Cydohexane 0.077 0.222 0.118 2-Melhylpentane 0.038 0.112 0.070 3-Methylpentane 0.023 0.066 0.041 n-Hexane 0.263 0.771 0.483 Methylcyclohexane 0.034 0.115 0.062 2,2,4-Trimethylpentane 0.000 0.000 0.000 Benzene 0.Q15 0.040 0.019 Toluene 0.044 0.137 0.065 Ethylbenzene 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

SPECIFICGRAVITY@60/60F, calculated
.................................................. . 1.0141 TOTALGPM (Ethane Inclusive)
............................................................... .. 13.943 CALCULATED BTU / REAL CF @ 14.73 PSIA, drybasis
................................ .. 1663.548 CALCULATED BTU / REAL CF@ 14.73 PSIA, wetbasis
.................................. 1635.316 AVERAGE MOLECULARWEIGHT
........................................................... . 29.370 MOLARMASS RATIO
............................................................................ .. 1.0141 RELATIVEDENSITY ( G x Z (Air) / Z ). calculated
........................................ 1.0215 IDEAL GROSS HEATING VALUE, BTU/ IDEALCF @ 14.696 PSIA
................. . 1647.712 COMPRESSIBILITY FACTOR (Z)
.............................................................. 0.99276

PROPANE GPM
................................................................................... .. 4.6583 BUTANEGPM
...................................................................................... . 2.3395 GASOLINE GPM (PENTANEAND HEAVIER)
......................................... .. 1.0627 

# • ()f I'HYSIC\! « ):\'TI '\TS H >1{ HYDI{()( II{BO,\S\,,'D OTHER ( ().\IP( >t**"I)~** (II I,rr I{I' ,1



# •

# •

29 Country Acres Rd, Riverton, WY 82501 Online. _.Pr.cl.lon-Lab•.com 

# PRECISION:::> 1!_.lb InfoCllPreclalon.Labs.cem Toll Fr •• Humbert (8&81 985-0866

# ~SfS
Client: BISON ENGINEERING Analysis Date: 10/11/2011 WILLIAMS Sample 10: TAT 2-1 Date Sampled: 10/11/2011 Unique #: Purpose: 

# • Sample Temperature: 117 DEG F Sample Pressure: 17 PSI Sampled By: TC Type Sample: ONLINE County: 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
..................... 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 Weight%. 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 

# "



# •

# •

ADDITIONAL BETX DATA



# • Components Mole % Weight % Liq. 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 OA08 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@6O/6O F, calculated
.................................................. . 1.1253 TOTALGPM (Ethane Inclusive)
................................................................. 16.864 CALCULATED BTU / REALCF @ 14.73 PSIA, drybasis
................................ .. 1874.169 CALCULATED BTU / REAL CF @ 14.73 PSIA, wetbasis
.................................. 1842.251 AVERAGE MOLECULARWEIGHT
.......................................................... .. 32.591 MOLARMASS RATIO
............................................................................. . 1.1253 RELATIVE DENSITY (Gx Z (Air) / Z),calculated
...................................... .. 1.1360 IDEAL GROSS HEATING VALUE, BTU /IDEALCF@ 14.696 PSIA
................ .. 1852.257 COMPRESSIBIUTYFACTOR (Z)
............................................................ .. 0.99058
PROPANE GPM
................................................................................... .. 5.5490 BUTANEGPM ...••••.....•.•••.•.....••....•.•........•••...........•........•....•....•••.....•••.. 3.3329 GASOUNE GPM (PENTANEAND HEAVIER)
.......................................... . 1.6803 

# • N{)TITj()"**~I.[ (1I.U!.\Tj(''':)PFRH)I(~IU)lSI''CPH1~1(**  \1 Ul"-'STI',bl I((l\! (.1'1**'I~~",l)** rH! LIBLr, Or PHYSIC\I (( )"'iT''']''; r' >1( H,DR( J( IRI.\(>"5 1"1) \ n HU, ( ('\II'! J1 \'1l5! )1' I;-';TfRLSl



# •

# •

29 Country Acres Rei. Riverton, WY 82501 Online, _.Preclslon-LIdos.cDm 

# PRECISION7 e......111 '"foCP_tsIOft·Labs.cDm Toll Free Number. (8.&) 985-0866

# ~SfS
Client: BISON ENGINEERING Analysis Date: 10/11/2011 WILLIAMS Sample 10: WELL 32-29 Date Sampled: 10/11/2011 Unique#: Purpose: 

# • SampleTemperature: 66 DEG F Sample Pressure: 20 PSI Sampled By: TC Type Sample: ONLINE County: DUNN
Components Mote % Carbon Dioxide
............. Hydrogen Sulfjde.....•..... Nitrogen
...................... Methane
...................... Ethane
......................... Propane
....................... iso-Butane
................... n-Butane
...................... iso-Pentane
... ,.............. n-Pentane
.................... Cyc!opentane
............... n-Hexane
..................... Cyc!ohexane
................ 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.Q15 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 &/0**Wei~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 @60/60 F, calculated
.................................................. . 1.0738 TOTALGPM (Ethane Inclusive)
................................................................. 16.499 CALCULATED BTU 1REAL CF @ 14.73 PSIA, dry basis
................................ .. 1796.792 CALCULATED BTU 1 REAL CF @ 14.73 PSIA, wet basis
................................. . 1766.229 AVERAGE MOLECULARWEIGHT
........................................................... . 31.101 MOLARMASS RATIO
............................................................................ .. 1.0738 RELATIVE DENSITY ( G x Z (Air) 1 Z ), calculated
....................................... . 1,0830 IDEALGROSS HEATINGVALUE. BTU 1 IDEALCF @ 14.696 PSIA
................ .. 1777.412 COMPRESSIBIUTYFACTOR (Z)
.............................................................. 0.99149

PROPANEGPM
................................................................................... .. 5.5702 BUTANEGPM
...................................................................................... . 2.5073 GASOUNE GPM (PENTANE AND HEAVIER)
........................................... 1.1204 ;-..:(n**IrH'~** II[ (ILU[**·In(l·,.'jlFI\H'R\[F.lllSl~(,PH)S/(** ,I**\()~:;T\~r.i"R(;\I(;P\** :1)'''''. nil lllll[ ; 'i" PHY,[( ,I (( ,'\,ST 'I"rs f( lR IlYDR()( '1Rlll)\.;; ·1'1) [lTHFR ( (j\[P( H

## 'I), '[ I"TI'RISl n, fill '0. HI 1\.11 C, I>**I~m** )1'R,



# •

# •

29 Country Acres Rd, Riverton, WY 82501 Online: -.Preclslon·Labs.com 

# PRECISION? E_III InfofllPreclslon.Labs.com Toll Free Numbert (8661 985-0866

# ~SfS
dient: BISON ENGINEERING Analysis Date: 10/11/2011 WILLIAMS Sample ID: WOLF 27-34 Date Sampled: 10/11/2011 Unique#: Purpose: 

# • Sample Temperature: 60 DEG F Sample Pressure: 30 PSI Sampled By: TC Type Sample: ONLINE County: 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
..................... 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

# •

ADDITIONAL BETX DATA Components Mole % Weight % 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 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 PSlA, dry basis
.................................. 1558.098 CALCULATED BTU / REAL CF @ 14.73 PSlA, wet basis
................................ .. 1531.712 AVERAGE MOLECULARWEIGHT
.......................................................... .. 27.065 MOLAR MASS RATIO
............................................................................. . 0.9345 RELATIVE DENSITY (G x Z (Air) / Z).calculated
........................................ 0.9403 IDEALGROSS HEATINGVALUE, BTU / IDEAL CF @ 14.696 PSIA
................ .. 1544.831 COMPRESSIBILITY FACTOR (Z)
.............................................................. 0.99377
PROPANEGPM
................................................................................... .. 3.1318 BUTANEGPM
..................................................................................... .. 1.4882 GASOUNE GPM (PENTANE ANDHEAVIER)
......................................... .. 1.4675 \;( n\TI()" \U (\U l. I. Hlu,," PIRFClR\lrn ! 'i1'.C, PHYSIC \1 (O'.;S1 ,,,T'i I'R( )\1 (;1' \ ,11i ",y' I Hr I \lll.f' 

# • 01 PH) 'il( \1 ( (I",T '" r'i f'()R**H~** OR( Ie**\RB()'.~** ,'.1) (ITHf'R < ( )\11'< II .,;n:; (II I, rrH' I f(l rHr ,UI R\J \'i l\;lll:iTIn



# •

# • ATTACHMENT F: ENGINE MANUFACTURER'S SPECS



# •

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



# • 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 e Utilizes ACERT- Technology • Reliable, rugged, durable design • Field-proven in multiple applications

worldwide • Four-stroke-cycle diesel engine combines

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

characteristics of diesel engines e Permanent magnet excitation 

# • • Segregated AC/DC, lowvoltage accessory box provides single point access 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 Arrangement shown with optional trailer 

# XQ230 

# SOUND ATTENUATED DUAL VOLTAGE 

## 50/60 Hz

ENVIRONMENTALLY FRIENDLY DESIGN • Sound attenuated for low noise operation • OSHA compliant safe design • 110% spill containment forcoolant and oil • UL142 certified dual wall fuel tank MULTI-VOLTAGE DISTRIBUTION PANEL • Simultaneous dual voltage • Load doorsafety switch • Rust-free hinges on all doors • Adequate space for line and plug connection

without interference • Remote start and stop contacts SINGLE-SOURCE SUPPLIER • Complete systems designed at Caterpillar

ISO 9001 :2000 certified facilities • CertHied PrototypeTested with torsional

analysis WORLDWIDE PRODUCT SUPPORT • Worldwide parts availabilitythrough the

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

200 countries, you're neverfar from the Caterpillar partyou need. • 99.7% of parts orders filled within 48 hours.

The best product support record in the industry. • Caterpillar dealer service technicians are

trained to service every aspect ofyour electric power generation system.

lEHE5329·03 

# •

# • RENTAL 

# C.l.TERPILLAR­



# • STANDARD FEATURES Air Inlet System Air cleaner, dua' element Turbocharger Charging System Battery charger Heavy duty charging alternator Control Panel Generator controls and monitoring Fuel tank monitoring Engine controls and monitoring Digita' displays Cooling System Fan and belt guards Base mountedradiator Air to air afteroooling Distribution Panel lockable doors load door safety switch, (trips breaker

upon door opening) Individual bus barconnections Circuit breaker with 24 VDC shunt trip Remote start/stop contacts Shore powerconnections Enclosure Sound attenuated 12-9auge stael lockable doors Separate vented battery compartment Single point lifting Exterior oil and waterdrainswith Interior valves Hidden exterior fuel drain Hand holds and steps Powder coated finish Fuel System Primary fuel fllter/water seperator UL142 dIJal wall fuel tank 1667 L(440 gall Radiator-mountad fuel cooler Genet'ator Brushlass, permanent magnet Coastal corrosion protection Shock mountedVR6 voltage regulator Space heater ULapproved Simultaneousthree-phase 4801277 and

240/139 voltage Mounting System Generator soft mountedto 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 withthermostat.

shut-offvalves 

### FACTORY INSTALLED STANDARD AND OPTIONAL EOUIPMENT OPTIONAL FEATURES Trailer Full frame support Independent tandem axle trailer frame

with tongue Electric actuatad hydraulic brakes

with rechargeable battery backup breakaway system. Overcenter mechanical parking brake Full length fenders Non-skid surface on steps Heavy duty safetychains 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 sensing with Volts-per-Hertz Voltage regulation•..•...••...•..•... :1: %% steady state/:I: %% no load tofull load TIF
...........................................Less than 50 

# • THO
.........................................Lessthan 5%



### TECHNICAL DATA



# • ENGINE C9 ATAAC, 4-stroke-cycle watercooled diesel Bore

- mm (in) ••..•.•.....•......•.•..••..••..•. 112 (4.41) Stroke

- mm (in)
................................ 149 (5.B7) Displacement- L(cu in)
..........." ....••......••B.B (537) Compression ratio
................................... 16.1:1 Aspiration••••••.••....•....Turbocharged AA charge cooled Engine control ••••••••....••...•.•.•..••..•.•.•ADEMTM A4 CAT CONTROL PANEL - EMCP 3.2 24Volt DC Control NEMA 1, 1P22 enclosure Lockable hinged door Enclosure mounted Single location customerconnector point 16 light alarm module with alarm horn Electric fuel level gauge Consultyour Caterpillardealerfor availableyoltages.

X0230 PowerRating

60Hz 50Hz ekYV INA StandbY TMlRef. PrIme 1M
..... 230 DM8S02 210 DM8512 275 DM85CM Engine andContainer lnformll1ion

Engine model Containerdimensions C9 see chartonjlage6 ShIppIngWeIght IDry)

Unit withtrailer kg Ub) 6210 (13,690) Unit without trailer MaximumFuelCapacityWeight kg IIbl 4960 (10,980)

Unit withtrailer kg UbI 7506 (16,5501 Unit without trailer kg Ubi 6278 (13.8401 Engine Lubrfc:atlng Oil Capacity Engine Coolant Capacity with Radiator Fuel Tank Capacity L(gall L(gall L(gal) 40 (10.551 36(9.61 1516 (400) Fuel Consumption lIhr(gaVl'lr) 69.2 418.3) 64.7 (17.1) Fuel Consumption (75% Prime) lIhr fgaVl'lr) 50.6 (13.4) RunningTune @ 75% Prime Sound Level hours 28

Standby dB(A) 74.72 No load @ 7 m (23 tt) dB(A) 70.20 Prime dB(A) 73.49 Ambient Capability Deg C (De9 F) 43 (109.4)

lEHE5329-03 3 

# •

# • RENTAL 

# C.ATERPILLARRATING DEFINITIONS AND CONDITIONS Meets or Exceeds International Specifications: • NEMA MG1-32, IEC 60034, CSA, 98/37/EEC, 72123/EEC,

UL 508, UL142, IS0304611,IS08528, 89/336/EEC Standby

- Output available with varying load for the duration ofthe interruption ofthe normal source power. Standby powerin accordance with IS08528. Fuel stop power in accordance with IS03046/1, AS2789, DIN6271, and B55614. Prime

- Output available with varying load for an unlimited time. Prime power in accordance with IS08528. 10% overload powerin accordance with 1503046/1, AS2789, DIN6271, and B56514 available on request. Ratings are based on 5AE J1349 standard conditions. These ratings also apply at 150304611, DIN6271, and B55514 standard conditions. Fuel rates are based onfuel oil of 35° API f@ 16° C (60· F)l gravity having an LHV of42 780 kJ/kg (18,390 Bt\.lllb) when used at 29° C (85·Fl and weighing 838.9 g/liter (7.0011b1U.5. gal). Additional ratings may be available for specific customer requirements. ConsultyourCaterpillar representative for details. 

# •

•

lEHE5329-03 4 

# •

# • RENTAL 

# C..lTERPILLARDISTRIBUTION PANEL 

# C"TERPILLAR'

..

# ~~.**I~)!:I** I F.

. ,,",

. iii

•.oco.!!!!.-.. .--... Wiring Descriptions 1. 800 amp main breaker 240V with 24V shunttrip 2. 400 amp main 480V with 24V shunt trip 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 amp 240V twistlock receptacle 8. 20 amp 240V twistlock receptacle 

# • 9. 20 amp 120V twistlock receptacle (2x) 10. 20 amp 120V groundfault interrupter, (2x) 11. 15 amp 120V ground fault 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 (Y2-) ground stud 16. Dual voltage load connection bus board [6.35 mm x 101.6 mm x 101.6 mm (YIN x 4" x 4M) bus bars1



# •

lEHE5329·03 5 

# •

# • RENTAL 

# C.TERPILLARe



### CONTAINER DIMENSIONS - TOP VIEW

m.e[lo.741-t---t-i

# r~

# -[----+--~~~ 1---------U39.7[245.16!------------l 

### CONTAINER DIMENSIONS - RIGHT SIDE VIEW 

# •

I
I Overall Dimensions Package With Trailer 

### I Length 4597.4mm 1S1in 6248.3mm 246 in 

### I Width 1498.6mm 69 In 2540.0mm 100 In 

### I Height 2387.6mm 94 In 2882.8 tnm 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 ENERGV INC. 

# EMISSION CONTROLDEVICES (ECD)


# •

Cimarron Energy Tank VOC 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 combustVOC emissions from the Oil/Condensate Production Tanks with clean efficient destruction. Cimarron ECDs have been independently tested 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: 10(580) 338·5496 FAX 1·(S60) 338·0885 P.O, Box '405. Guymon, Oklahoma 731W2 Administrativ.Offiee: 1·(405) 928·7373 FAX 1·(405)'928·7380 P.O. So> 722110. Norman, Oklahoma 73010 

# •

## --- I ! 

# \)

I**~** 

# ! 

# '0' 01\ 

## .1 B 

# r·- I' 

# C •

I

# ~"'f~1i**~J** 10f--;'\"'-
..
_ ------,--- 

# (J 

# S)t; 

# •**W~ ""~j**  , 

# • •

w 48" DlAx302 sJrrHEIGHT, 88 ORIfICES EMISSION <DNTROl DEVICE 

### '* >98%lVOC ORE. CERTIfIED USEPA 40 CFR 00, APPENDIX A, SOURCE EMMISIONS TEST METHODS REFERS«:ED. MEETS ALL EPA & CDPHE REGULATIONS.

.. DfSTROYS OIIJCONDENSATE PRODUCTION TANK VAPORS WI NO VISIBLE FlAME.

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ATTACHMENT H: PROCESS FLOWDIAGRAM OF FACILITY


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ATTACHMENT I: PRODUCTION DECLINE CURVE CALCULATIONS



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

# •

# • ATTACHMENT

# J: DIESEL TANK EPA TANKS 4.09D EMISSIONS SUMMARY



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

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# • • • • TANKS 4.0 Report Page 1 of

### 6

Identification User Identification: City: State: Company: Type of Tank: Description:
. Tank Dimensions Shell Length (It): Diameter (It): Volume (gallons): Turnovers: Net Throughput(gal/yr): Is Tank Heated (y/n): Is Tank Underground (y/n): Paint Characteristics Shell Color/Shade: Shell Condition Breather Vent Settings Vacuum Settings (psig): Pressure Settings (psig) 

### TANKS 4.0.9d Emissions Report - Detail Format Tank Indentification 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)



### 9/29/2011 

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# • • • • TANKS 4.0 Report Page 2 of6
TANKS 4.0.9d Emissions Report - Detail Format Liquid Contents of Storage Tank 1000 gallon diesel tank - Horizontal Tank Williston, North Dakota**.----~-----------------** 

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### --.---.-- LIquid T Daily Liquid Surf. emperalUre (deg F) Bulk Temp vapor Pressure (psis) Vapor Mol. LIquid Mass vapor Mass Mol. Basis for Vapor Pressure MixlureJCompOnent Month Avg, Min. Ma•. (deg F) Avg. MII1. Ma•. Weight. Fract. Fract. Weight Calculations**--------~---.-----------------------** Distillate fuel oil no. 2 All 50.16 39.72 60,64 44.68 0.0045 0.0031 0.0067 130.0000 188.00 Option 1: VP50 .0045 VP60 •. 0065



### file:IIC:\Program Files\Tanks409d\summarydisplay.htm 9/2912011

# • • • • 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 Calcaulatlons Standing Losses (Ib):

Vapor Space Volume (cu It): Vapor Density (lb/cu It): Vapor Space Expansion Factor: Vented Vapor Saturation Factor: Tank Vapor Space Volume:

Vapar Space Volume (cu It): Tank Diameter (It): EflecliYe Diameter (It): Vapor Space Outage (II): Tank Shell Length (ft): Vapor Density

Vapor Density (II)/cu It): Vapor Molecular Weight (Ibltb·mole): Vapor Pressure at Dally AYerage Liquid

Surtace Temperatule (psia): Dally AYg. Liquid SUltace Temp. (deg. R): Daily AYelage Amblen! Temp. (deg. Fl: Ideal Gas Constanl R

(psla cull I (Ib·mol·dag R»: Liquid Bulk Temperature (deo. R): Tank Paint SolarAbsorptance {Shell}: Daily Total Solar Insulalion

Faclor (Blulsqfl day): Vapor Space Expansion Factor

Vapor Space Expansion Faclor: Daily Vapor Tempera,"re Range (dog. R): Daily Vapor Pressure Range (psia): Brealher Vent Press. Sening Range(psla): Vapor Plessure al Daily Ayerage Liquid

Surtace Temperature (pslal: Vapor Pressure al Daily Minimum Liquid

Surtace Temperature (psia): Vapar Pressure at Dally Maximum Liquid

Surtace Temperature (PSIa): Daily Ayg. Liquid Surtace Temp. (dag R): Daily Min. Liquid Surlace Temp. (dag R): Daily Max. Liquid Surtace Temp. (deo R): Daily Ambienl Temp. Range (dag. R): Venled Vapar Saluration Factor

Vented Vapor Saluralion Factor: Vapar Pressure at Dally Ayeraga Liquid:

Surface Temperature (psia): Vapar Space Outage (It): Working Losses (Ib):

Vapar Molecutar Weight (IbIIb-mole): Vapor Pressure at Daily AYerage Liquid

Surface Temperalure (psia): Annual Net Throughpul (gallyr.):
. 0.2654 86.5719 0.0001 0.0780 0.9995 86.5719 4.1800 7.2797 2.0800 10.0000 0.0001 130.0000

0.0045 509.8466 41.5958

10.731 5043458

0.6800 1,276.2450 0.0780 41.8377 0.0036 0.0600 0.0045 0.0031 0.0067 509.8466 499.3872 520.3060 24.3583 0.9995 0.0045 2.0800 5.6720 130.0000

0.0045 2,244,312.0000 

### file:IIC:\Program FiJes\Tanks409d\summarydisplay.htm 91291201 )

# • • • 

# • TANKS 4.0 Report Page 4 of6

Annual Turnovers: 2,244.3120 Turnover Factor: 0.1800 Tank Diameter (ft): 4.1600 Working Loss Product Faclor: 1.0000 Total Losses (Ib)' 5.9375

file:IIC:\Program Files\Tanks409d\summarydisplay.htm 9/2912011

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# • • • 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 

### II Losses(lbs) 

### I [<::omponerits 

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

## II 5.67/1 0.2711 5.941



### file:IIC:\Program Files\Tanks409d\summarydisplay.htm 9/2912011

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# • • • TANKS 4.0 Report Page 60f6



### file:IIC:\Program Files\Tanks409d\summarydisplay.htm 9/29/2011