# •

APPLICATION FORAN NSR PSnffITLE V SYNTHETIC MINOR AIR QUALITY PERMIT OLSON-FBIR 

# PAD OIL & 

# GAS

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Preparedby: 

### Bison Engineering, Inc. 

## 1400 11th

www.

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### December 29, 2011 --­ 

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# •

DAKOTA·3 E&P COMPANY, LtC 8 subsldinryofWlJllnms 1001 17'" Slreel. Suile 1200 Denver, CO 80202 303/527·3900 

# DEC 2') 

# 2011 

# 8P-AR December 29, 20JI

Ms. Kathleen Paser Duplicate submittal provided via e-mail to: Minor NSR Permitting Coordinator r8airpennitting@epa.gov 

# • U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129 Re: Synthetic Minor Source Permit Application for the Olson-FBlR Pad Dear Ms. Paser: Dakota-3 E&P Company, LLC (Dakota-3) a subsidiary ofWilliams is submitting this Synthetic Minor Source Permit Application for the Olson-FBIR Pad. This application is being submitted in accordance with the requirements ofFederal MinorNew Source Review Rule. Do Hot hesitate to contact me with any questions either by phone at 303-606-4056, or bye-mail at JoDeII.Mizoue@Williams.com. Sincerely, 

# • JoDell Mizoue, P.E StaffEnvironmental Specialist Attachment cc: File Joe GilliesJr. Envjronmental Director, Environmental Division, 204 W. Main, New Town, ND 58763-9404 Tex Hall, Chairman Three Affiliated Tribes. 404 Frontage Road, New Town, ND 58763-9404 (letter Only) 

# •

# • C. 

### CONTACT INFORMATION



# •

• Company Contact: JoDell Mizoue Title: StaffEnvironmental Specialist Mailing Address: 1001 17tlt Street, Suite 1200 Denver, CO 80202 Email Address: JoDell.Mizoue@Williams.com Telephone Number: (303) 606-4056 FacsimileNumber: (303) 692-8285 

### Operator Contact (ifdifferent from companycontact): Same as above Title Mailing Address Email Address TelephoneNumber FacsimileNumber 

### Facility Contact: Same as above Title Mailing Address Email Address TelephoneNumber Facsimile Number 

### Compliance Contact: Same as above Title Mailing Address Email Address TelephoneNumber FacsimileNumber



# •

### D. ATTACHMENTS 

# •



# •

•



# • Include all ofthe following information (see the attached instructions) ./ FORM SYNMIN
- New Source Review Synthetic Minor Limit Request Form, ifsynthetic minor limits are being requested. ./ Narrative description ofthe proposed productionprocesses. This description should follow the flow of the process flow diagram to be submittedwith this application. ./ Process flow chart identifying all proposed processing, combustion, handling, storage, and emissioncontrol equipment. ./ A list and descriptions ofall proposed emissionunits and air pollution-generating activities. ./ Type and quantity offuels, including sulfur content offuels, proposed to beused on a daily, annual and maximum hourly basis. ./ Type and quantity ofraw materials used or final product produced proposed 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. ./ Criteria PollutantEmissions
- Estimates ofCurrent Actual Emissions, Current Allowable Emissions, PostChange Uncontrolled Emissions, and Post-Change Allowable Emissions for the following airpollutants: particulate matter, PMIO, PM2.5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead compounds, fluorides (gaseous and particulate), sulfuric acid mist (H2S04), hydrogen sulfide (H2S), total reduced sulfur (TRS) and reduced sulfur compounds, including all calculations for the estimates. ./ These estimates are to be made for each emissionunit, emission generating activity, and theproject/facility in total. ./ Modeling
- Air Quality ImpactAnalysis (AQIA) ./ ESA (Endangered Species Act) ./ NHPA (NationalHistoric PreservationAct)

# • E. TABLE OF ESTIMATED 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 top ofthe form. 

### EO)
- Proposed New Facility


# • Pollutant PotentialEmissions (tpy) Proposed Allowable Emissions (tpy) PM
- Particulate Matter PM IO - Particulate Matter less than 10 microns in size PM2.5 ­ Particulate Matterless 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 H2 S - Hydrogen Sulfide TRS
- Total Reduced Sulfur RSC
- Reduced Sulfur Compounds PM 

### 0.61 0.76 PMu 

### 0.61 0.76 PM 2.S 

### 0.61 0.76

SOl 

### 0.16 0.16 NO. 

### 36.93 40.27 CO 

### 75.18 93.37 VOC 

### 1816.12 94.98

Pb 

### Negligible Negligible Fluorides 

### Negligible Negligible

H2SO 4 

### Negligible Negligible H2S 

### Negligible Negligible TRS 

### Negligible Negligible RSC 

### Negligible Negligible Emissions calculations must include fugitive emissions ifthe source is one the following listed sources, pursuant to CAA Section 3020): (a) Coal cleaningplants (with thermal dryers); (b) Kraft pulp mills; (c) Portlandcementplants; (d) Primary zinc smelters; (e) Iron and steel mills; (f) Primary aluminumore reduction plants; (g) Primary copper smelters; 

# • (h) Municipal incinerators capable ofchargingmorethan 250 tons ofrefuseper day; (i) Hydrofluoric, sulfuric, ornitric acid plants; 

### 0) Petroleum refineries; (k) Lime plants; (I) Phosphate rock processingplants; (m) Coke oven batteries; (n) Sulfur recoveryplants; (0) Carbon black plants (furnaceprocess); (P) Primary lead smelters; (q) Fuel conversion plants; 

# ( 

# 1 •

• I (r) Sinteringplants; (s) Secondarymetal productionplants; 

# I (t) Chemical processplants (u) Fossil-fuel boilers (orcombination thereof) totaling 

# I more than 250 million British thermal units perhour heat input; 

# { (v) Petroleum storage and transfer units with a total storage capacity exceeding 300,000barrels; (w) Taconite ore processing plants; (x) Glass fiber processingplants; (y) Charcoal production plants; 

# I (z) Fossil fuel-fired steam electric plants ofmorethat 

# I I 250 million British thermal unitsperhourheat input, and (aa) Anyother stationary source category which, as of August 7, 1980, is beingregulated under section III or 112 ofthe Act. 

# I I 

## I


# •

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

# •



# •

•



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

## N/A N/A N/A N/A PM 10 

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

## N/A N/A 

## N/A N/A

SO, 

## N/A N/A N/A N/A NO, 

## N/A N/A 

## N/A N/A CO 

## N/A N/A N/A 

## N/A VOC 

## N/A N/A 

## N/A N/A

Pb 

## N/A N/A 

## N/A N/A NH3 

## N/A N/A 

## N/A N/A Fluorides 

## N/A N/A 

## N/A N/A

H2SO 4 

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

## N/A N/A 

## N/A N/A TRS 

## N/A 

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

## N/A N/A N/A N/A PM
- PartIculate Matter PM'Q
- Particulate Matter less than 10microns 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 andparticulates H

2S0 4 - 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 evaluatedto determine ifthe change is major under the majorNSRprogram using the procedures at 40 CFR 52.21 (i.e., baseline actual to projected actual applicability test). Iftheproposed construction does not qualifY as a major under that test, then it may be subject to the requirements ofthe minorNSR rule at 40 CFR 49.151. 

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


### • 40 CFR 49.J

### 52(d)
- Modification means anyphysical or operational change at a source that would cause an increase in the allowable emissions ofthe affected emissions units for anyregulated NSR pollutant orthat would cause the emission ofanyregulated NSR pollutant not previously emitted. 

# • The following exemptions apply: (1) Aphysical or operationalchange does not include routine maintenance, repair, orreplacement. (2) An 

### increase inthe hours ofoperation orin the productionrate is not considered anoperational change unless such increase is prohibited under any federally-enforceable permit conditionor other permit conditionthat is enforceable as a practical matter. (3) A change inownership at a source is not considered a modification.


### • 40 CFR 49.

### J52(d)
-Allowable emissions means "allowable emissions" as defmed in 

# I §52.2I(b)(16), except thatthe allowable emissions for any emissions unit are calculated considering any emission limitations that are enforceable as a practical matter onthe emissions unit'spotential to emit. 

## r i • 52.2J(b)(J6)
-Allowable emissions means the emissions rate ofa stationary source calculated 

# i using the maximumrated capacity ofthe source (unless the source is subject to federally enforceable limits which restrict the operating rate, or hours ofoperation, orboth) and the most 

# l stringent ofthe following: 

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

# • (ii) The applicable State Implementation Plan emissions limitation, including those with a future compliance date; or (iii) The emissions rate specified as a federally enforceablepermit condition, including those with a future compliance date.

Page 7 ofl5 

# •

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# •

•

• A. General Facility Information 1. Company Name & OperatorName (ifdifferent): Provide the complete company and operator names. For corporations, include divisions or subsidiaryname, ifany. 2. Facility Name: Providethe facility name. Pleasenote that a facility is a site, place, location, etc... that may contain one or more air pollution emitting units. 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? Some examples ofportable sources include asphalt batchplants and concrete batchplants. 5. TemporarySource: A temporary source, in general, would have emissions that are expected last less than 2 years. Doyou expect to cease operations withinthe next 2 years? 6. NAICS Code: North American Industry Classification System. TheNAICS Code for your facility canbe found at the following link North American Industry Classification System (http://www.census.gov/epcd/naics/nsic2ndx.htm#Sl). 7. SIC Code: Standard Industrial Classification Code. AlthoughthenewNorth AmericanIndustry Classification System(NAICS)has replaced the SIC codes, muchoftheClean Air Actpermittingprocesses continuetouse these codes. The SIC Code for yourfacility can befound at the following link Standard Industrial Classification Code(ht1:j:l:llwww.osha.gov/plslimis/sic manua1.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 Indianreservation within whichthe facility is operating. 10. County: Provide the Countywithin which the facility is operating. Ila & lIb. Latitude & Longitude: These areGPS (global positioning system) coordinates. This information canbe provided in decimal format ordegree-minute-second format. 12a 12d. Section-Township-Range: Pleaseprovide these coordinates in 114 SectionlSection/TownshiplRange. (e.g., SW 1/4, NE %/S36ITI0NIR21E).

Page 8 of 15

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

### C. Contact Information Pleaseprovide the information requested in full. I.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. CompJiance Contact: The compliance contact must be the local contact responsible for the facility's compliance with this rule. Ifthis is the same as the Facility Contactpleasenote this on the form. 

### D. Attachments This section lists the information needed to completethe requested approval. This information should be accompanied bythe supporting information listed onthe form and described below. The information should be presented in enough detailto 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 proposedproductionprocesses. 

# • 1. The narrative description should follow the flow oftheprocess flow diagramtobe submitted with this application. This needs to beas comprehensiveas possible to help in understanding the proposed facility and how it will beoperated. For example: What are theraw materials? What are theproperties oftherawmaterials? Does the productionprocess 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 (Le., crushed ore, dry gas, water, etc...)? Etc.... 

### 2. The proposed operating schedule presented in terms ofhours perday, days per week, and weeksperyear. 3. A list ofthe type and quantity offuels and/or raw materials used. Each fuel and raw material should be described in enough detailto indicate its basic chemical components. Page 9 of 15 

# •

# •

•

•



# • ./ Aprocess flow chart identifying all proposed processing, combustion, handling, storage, and emission control equipment (include the unit identification # or code), This flow chart should illustrate the detailed narrative description requested above. ./ List and describe allproposed units, emissionunits and air pollution-generating activities. At a minimum, provide the following: 1. The hourly, dailyand annual maximum operating rates for each operating unit, productionprocess, and activity. 2. The hourly, daily and annual maximum firing rates for each fuel and combustion equipment. 3. The capacity for storage units and the hourly, daily and annual maximumthroughput ofmaterial in the storageunits. 4. Material and product handling equipment and thehourly, daily and annual maximum throughput ofmaterial and product. 5. Tank designs, tank storage capacities, hourly, daily and annualmaximumthroughput ofmaterial and product. ./ 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 producedproposedto beused on a daily, annual and maximum hourlybasis. ./ Proposed operating schedule, including number ofhours per day, number ofdays per week and number of weeks peryear. ./ A list and description ofall proposed emission controls, control efficiencies, emission limits, and monitoring for each emissionunit and air pollution generating activity. 1. Include manufacturer specifications and guarantees for each control device.

Page 10 ofl5

# • 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, PM,o, PM2 .5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead compounds, ammonia (NH3), fluorides (gaseous and particulate), sulfuric acid mist (H2S04), hydrogen sulfide (H2 S), totalreduced sulfur (TRS) and reduced sulfur compounds, including all calculations for the estimates. 1. 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 (tonsperyear) units. 3. Any emission estimates submitted to the Regional Administrator must be verifiable using currently accepted engineering criteria. The following procedures are generaUy acceptable for estimating emissions from air pollutionsources:
• Source-specific emissiontests; • Massbalance calculations; • Published, verifiable emission factors that are applicable tothe source. (i.e. 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/ttnichief/efPac/index.html. Current Actual Emissions: Current actual emissions for a pollutant is expressed intpy and generally is calculated by mUltiplying the actualhourly emissions rate in pounds perhour (lbslhr) times actual hours operated (which is the number ofhours in a year) and dividing by 

### 2,000 (which is thenumber ofpounds in a ton). 

# • 1. For an existing airpollution source (permitted and unpermitted) that operatedprior to the application submittal, the current actual emissions are the actual rate ofemissions for the preceding calendar year and must becalculatedusing the actual operating hours, production rates, in-place control equipment, and types ofmaterials processed, stored, or combusted during thepreceding calendar year. The emission estimates must bebased 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 tpy and generally is calculated by mUltiplying the allowedhourly emissions rate in pounds perhour (lbslhr) times allowed hours (which is thenumber ofhours in a year) and dividing by 

### 2,000 (which is the number ofpounds in a ton). I. "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 anyemissions limitations that are enforceable as a practical matter onthe unit's PTE. 2. For an existing permitted airpollution sourcethat operatedprior to the application submittal, the current allowable emissions arethe allowable rate ofemissions for thepreceding calendaryear and must be calculated using thepermittedoperating bours, production rates, in-place control equipment, and types ofmaterials processed, stored, or combusted during the preceding calendar year. 

### 3. For an existing air

### pollution sourcethat does not have an established allowable emissions level prior to the modification must report the pre-change uncontrolled emissions. Post-Change Potential Emissions (Potential uncontrolled emissions from proposedproject): This is the maximum capacity ofa source to emit a pollutant under its physical and operational design. This is expressed in tpyand generally is calculatedby mUltiplying the maximum hourly emissions rate inpoundsper hour (lbslhr) times 8,760 hours (which is the number ofhours in a year) and • dividing by2,000 (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 inpoundsperhour (lbs/hr) 

### times allowed hours (which is the number ofhours in a year) and dividing by2,000 (which is the number ofpounds in a ton). 1. Unless the source is restricted bypermit conditions orother requirements that are enforceable as a practical matter, the post-change allowable emissions would be equivalent to post-change uncontrolled emissions. For the post-change allowable emissions a lowerlevel ofallowable emissions maybeproposed. 2. Forphysicalor operational changes at minor sources and for minor physical 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 bethe potential to emit ofeachunit. • For each emissions unit with an allowable emissions limit that is to be changed or replaced, the emissions increase would be the allowable emissions ofthe emissions unit after the change orreplacement minus the allowable emissions prior to the change or replacement. However, this may not be a negative value. Iftheallowable emissions ofan 

# • emissions unit would be reduced as a result ofthe change orreplacement, use zero in the calculation. • For each unpermitted emissions unit (i.e., a unit without any emissions limitationsbefore the change) that is to be changed orreplaced, the emissions increase would be the allowable emissions ofthe unit after the change orreplacement minus the potential to emit priorto 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 inthe calculation. 

# • Page 12 of 15

# • ./ Modeling Analysis 

### Do I need to do a modeling analysis? The Federal Minor New Source Review Regulations at 40 CFR49.159(d) requires that a modeling analysis (AQIA) ofproposed emissions beperformed ifthere is reason tobe concerned that new constructionwould cause or contribute to a National Ambient Air Quality Standard (NAAQS) or Prevention ofSignificant Deterioration (PSD) increment violation. 

### In addition, ifthe AQIAreveals that the new constructioncould cause orcontribute to a NAAQS or PSD increment violation; such impacts must 

### be reduced before a pre-constructionpermit can

### be issued. 

# • To facilitate the protection ofthe NAAQS and PSD Increment, EPA Region 8 requests that those proposed activities that meet the following criteria perform an AQIA: 1. Theproposed 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 usuallywarranted, even though the proposed activity does not meet the modeling requirements, above, ifit is reasonable to believe the new activity may cause or contribute to a violationofapplicable ambient air quality standards orincrements in circumstances such as: (a) A substantialportion 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 proximityto the source); or (c) Thenew ormodified emissions are located in areas with existing air quality concerns. (d) Ifyou have questions about whether modeling maybe necessary based onthe 4th 

### criteria above, please contact EPA Region 8'sModeling Lead: 

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

Page 13 of 15 

# •

# • What Kind ofAir Quality Modeling Analysis Is Needed? ] . EPA Region 8 considers a stepped or phased approach to modeling tobe appropriate, as follows: Step I: Qualitative Air Quality Assessment Step2: Screening Modeling Analysis Step 3: Preliminary Modeling Analysis (refined modeling) Step4: Full Impact Modeling Analysis (refmed modeling) Step 5: PSD Increment and NAAQS Analysis Step 6: Additional Impact Analysis 

### 2. Step I: Qualitative Air Quality Assessment Narrative description ofthe current air quality conditions and the expected impact the permitted source 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 qualitywouldbe expected, a screening analysis should next be performed. 3. Step

### 2: ScreeningAnalysis For proposed new or modified sources that meet the modeling requirement criteria identified above, protectionofair quality from proposed emissions maybe shownby using a simple screening technique (e.g., SCREEN3 orAERSCREEN). Screening models are available for download atthe EPA SCRAM website: http://www.epa.gov/ttniscramldispersionscreening.htm. A pre-approved modeling protocol is not necessary priorto conducting a Screening Analysis. 4. 

### Ifthe proposed new or modified emission increases do not increase ambient concentrations ofa pollutant bymore than the significant impact levels, as compared to the SILs identifiedbelow, no further modeling is necessary. 

# so

19D1 

### °fi

lcant 

### Impact 

### Leve s 

### I Pollutant Averaging Period Class IIArea 

### SIL (uglm3) 

### ClassI Area 

### SIL (ug/m3) S02 I hr 3 ppb or 7.8 uglm' (interim) ---­ 3hr 25 1.0 24hr 5 0.2 Annual I 0.08 

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

### PMJO 24hr 5 0.2 Annual 1 0.08 

### N02 I hr 4 ppbor7.5 ug/mj (interim) 

### ---­ Annua1 1 0.08 

### CO 1hr 2,000ppb 8 hr 500ppb 

# •

•



# • Note: The Class 1area SILs are provided as guidance and have not been formalized by EPA.
Page \4 of 15

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

### Step 3 through

### Step 6. Modeling in Steps 

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

### What Should I Include In My Application IfModeling Is Necessary? 1. Approved Modeling Protocol In orderto expedite the permitting process, it 

### is recommended that you include a protocol that has already been approved. 

### An application will notbe deemed complete until the protocol has beenapproved. 

# • 2. Modeling Results In all 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 consultation with the US. Fish and Wildlife Service andlorthe NOAA Fisheries 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 bereadily aware ofthat couldbe affectedby yourproposal. The following website has beenprovided to assist you: http://www.fWs.gov/endangeredl Simply enterthe State and County in which you proposeto construct to obtain a general listing. 

# • ./ NHPA The NationalHistoric Preservation Act requires us, in consultation with State andlor Tribal Historic Preservation Officers to ensure that actions we authorize are not likely to affect culturalresources. To expedite the approval ofyourproposed 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 hasbeenprovided to assist you: http://nrhp.focus.nps.gov/natreghome.do?searchtype=natreghome Simply enter the State and County in which you propose to construct to obtain a general listing.

Page 15 of 15 

# •

# • UNITED STATES ENVIRONMENTALPROTECTION AGENCY I: 

### Region 8 AirProgram FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

## Checklist· Synthetic Minor Limit Request (Form SYNMIN) Use ofthis information request form is voluntary and not yet approved bythe Office ofManagement and Budget. The following is a check listofthetype ofinfonnation that Region 8will use to process infonnation on your proposed project. While submittal ofthis fonn 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 fonns for this program is currently under Office ofManagement and Budgetreview and these infonnation request forms will be replaced/updated after thatreview is completed. Please submitinformation to following two entities:

Company Name Dakota-3 E&P Company, LLC Facility Name Olson-FBIR Pad Company Contactor Owner Name JoDell Mizoue Title StaffEnvironmental Specialist Mailing Address 1001 17UJ Street, Suite 1200 Denver, CO 80202 Email Address JoDell.Mizoue@Williams.com Telephone Number (303) 606-4056 

# I Facsimile Number : (303) 692-8285 The Tribal Environmental Contact for the specific reservation: 

# • Ifyou need assistance in identifying the appropriateTribal Environmental Contact and address, pleasecontactthe EPA Region 8 Tribal Air Coordinator: Alexis North, EPA Region 8 Tribal Air Coordinator 303-312-7005 north.alexis@epa.gov



# •

• Foreach criteria airpollutant, hazardous airpollutant and for all emission units and airpollutantgenerating activities to be covered by a limitation, include the foDowing: ./ Item 1 - Theproposed limitation and a description ofits effect on current actual, allowable and thepotential to emit. ./' Item2 - The proposed testing, monitoring, recordkeeping, and reporting requirements to be used to demonstrate andassure compliance with the proposed limitation. ./ Item3 - A description ofestimated efficiency ofairpollution control equipment under present or anticipated operating conditions, including documentation ofthemanufacturer specifications and guarantees. ./' Item4 - Estimates ofthe Post-Change AllowableEmissions that would result from compliance with theproposed limitation, including all calculations for the estimates. ./ Item5 - Estimates ofthepotential emissions ofGreenhouse Gas (GHG) pollutants before and after proposed emission controls. Federal MinorNSRPermit Coordinator U.S. EPA, Region 8 1595 WynkoopAvenue, 8P-AR Denver, CO 80202-1129



### A. GENERAL INFORMATION

B. ATTACHMENTS

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

### 1. Who Can Request Federally-Enforceable Limitations Underthe Tribal NSR Authority? The Tribal NSR Rule applies onlyto sources located within the exteriorboundaries ofan Indian reservation in the United States ofAmerica orother lands as specified in 40 CFR part 49, collectively referred to as "Indian country". So, to use the authority in the Tribal NSRRule to create federally­ 

# • enforceable limitations, a facility must be located within Indian country. Land ownership status (for example, whetherthe land is owned bya Tribal member orwhether the land is owned in fee or in trust) does not affect how the rule applies. 2. WhoMightWantto Request Federally-Enforceable Limitations? The primaryreason for requesting federally-enforceable limitations is to avoid anotherwise applicable federal Clean Air Actprogram, rule orrequirement. Many federal CleanAir Act programs use a source's "potential to emit" (PTE) air pollutionto determine which rules orrequirements apply. A facility's PTE 

### is based onthe maximum annual operational (production, throughput, etc) rate ofthe facility taking into consideration the capacity and configurationoftheequipment and operations. Emission oroperational limits can also betaken into consideration as maximums ifthey are federally enforceable. So, using a synthetic minorNSR permit to establish federally enforceable limitations can lower a facility's PTE and possibly allow the facility to avoid certain federal CleanAir Act requirements. Three examples offederal Clean Air Act programs that use PTEto determine whetherthey apply are (1) the PreventionofSignificant Deterioration (PSD) construction permitting program, (2) the Title V operating permitprogram. and (3) the Maximum Achievable ControlTechnology (MACT) program. For example, existing sourcesthat are considered "major" for Title V (meaning they have thepotential to emit air pollution at levels defined in that rule as "major") must apply for a Title V operating permit. 

### Ifa source accepts a federally-enforceable limitation through a synthetic minor NSRpermit 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, thenthe 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 on PTE (using a synthetic minor NSRpermit) that allow the source to avoid PSD. Limitations onPTE can similarly help a source to avoid new MACT standards that would otherwise apply to the source. 3. Section B. ATTACHMENTS This section lists the information that mustbe attached tothe application form for each requested limitation. The requested limitation(s) must be described for each affected emissions unit (orpollutantgenerating activity) and pollutant and must be accompanied bythe supporting information listed onthe form and described below. Notethat applicability ofmany federal CleanAirAct requirements (such as Title V, PSD and MACT) is often based on facility-wide emission levels ofspecific pollutants. In that 

# • Page 2 of4

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

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

### Item 

### 2
- Foreach requested limitation, the application must include proposed testing, monitoring, recordkeeping andreporting that will be used to demonstrate and assure compliance with the limitation. Testing approaches should incorporate and reference appropriate EPAreference methods where applicable. Monitoring should describe the emission, controlorprocess parametersthat will be relied onand should address frequency, methods, and quality assurance. 

### Item 3
- The application must include a description and estimated efficiency ofair pollution control equipment underpresent or anticipated operating conditions. Forcontrol equipment that is not proposed to be modified to meet the requested limit, simply notethat 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 eachcontrol device. 

### Items 4 - 

### Any emissionestimates submitted to the Regional Administratormustbe verifiable using currently accepted engineering criteria. The following procedures are generally acceptable for estimating emissions from air pollution sources: (i) Source-specific emission tests; (ii) 

### Mass balance calculations; (iii) Published, verifiable emission factors that are applicable to the source. (i.e., manufacturer spedfications). 

### (iv) Other engineering calculations; or (v) Otherproceduresto estimate emissions specifically approved by the Regional Administrator. Post-Change AllowableEmissions: A source's allowable emissions for a pollutant is expressed in tpy and generally is calculated by mUltiplying the allowed hourly emissions rate inpounds 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). 

### Item 5
- New construction projects 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 75,000tpy C02e and minor sources that increase GHG emissions by at least 100,000 tpy C02e and 100 or250 tpy on a mass basis are subject to PSD permitting requirements, even ifthey do not significantly increase emissions ofanyotherpollutant. As such, any requested limits to avoid PSD must take into account greenhouse gases. Therefore, please include in yourpermit application estimates ofthepotential emissions ofthe following pollutants before and after proposed emission controls. More information about GHG permitting andhow to calculate C02 equivalents (C02e), the mass emissions ofeach individual GHG

Page 3 of4 

# •

•



# •

# • adjusted for its Globa1 Warming Potential (GWP) can be found at: http://epa.gov/nsr/ghgdocs/ghgpermittingguidance.pdf 1. Carbon dioxide (C02) 

### 2. Methane (CH4) and its C02C 3. Nitrous oxide (N20) and its C02C 4. Hydrofluorocarbons (HFCs) and its C02c 5. Perfluorocarbons (PFCs) and its C02e 6. Sulfur hexafluoride (SF6) and its C02e 

# •

•



# • Page 4 Qf4

# • OLSON-FBIRPAD ATTACHMENTS:



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

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


# •

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

# •

# •
ATTACHMENT A: APPLICATION REPORT



# •



# •

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

# •

# •

• APPLICATION FORAN NSR PSD/TITLE V SYNTHETIC MINOR AIRQUALITY PERMIT OLSON-FBIR PAD OIL & 

# GAS PRODUCTION FACILITY

Prepared for: 

### Dakota-3 E&P Company, LLC 100117th Street, Suite 1200 Denver, CO 80202

Preparedby: 

### BisonEngineering, Inc. 1400 11th Avenue 

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



### December 29, 2011 

# •

# • TABLE OF CONTENTS 1.0 INTRODUCTION
.................................................................................................. 1 1.1 Summary
................................................................................................... 1 1.2 Site Location
.............................................................................................. 1 1.3 Site Description
.......................................................................................... 1 2.0 NARRATIVE DESCRiPTION
................................................................................3 3.0 POTENTIAL TO EMIT ESTIMATE
.......................................................................5 3.1 Production Storage Tank VOC Emissions
................................................. 8 3.2

....... 9 Produced Casing Head Gas Emissions
.....................................................8 

# • 3.3 Reciprocating Internal Combustion or Compression Ignition Engines 3.4 Natural Gas External Combustion Unit Emissions
..................................... 9 3.5 Truck Loading Emissions
...........................................................................9 3.6 Fugitive Emissions: Dust and Equipment Leaks
....................................... 9 4.0 EMISSIONS AND OPERATIONAL LIMITS REQUESTS
................................... 10 4.1 Production Storage Tank Emissions
........................................................ 10 4.2 Reciprocating Internal Combustion or Compression Ignition Engines
..... 10 5.0 ALLOWABLE EMiSSiONS
................................................................................. 11 5.1 Storage Tank Emissions
.......................................................................... 11 5.2 Produced Casing Head Gas Emissions
................................................... 11 5.3 Rice Engine Emissions
............................................................................ 11 5.4 Natural Gas External Combustion Unit Emissions
................................... 11 5.5 Truck Loading Emissions
......................................................................... 12 5.6 Fugitive Emissions: Dust and Equipment Leaks
..................................... 12 5.7 Diesel Storage Tank Emissions
............................................................... 12 6.0 PROPOSED MONITORING AND RECORDKEEPING
...................................... 13 6.1 Production Storage Tanks
....................................................................... 13 6.2 Production Storage Tank Emissions Control Device
............................... 14 6.3 Produced Casing Head Gas Emergency Utility Flare
.............................. 16 

# • 6.4 Rice Engines
............................................................................................ 17 6.5 Natural Gas-Fired External Combustion Units
......................................... 17 6.6 Truck Loading
.......................................................................................... 18 6.7 Fugitive Emissions: Dust and Equipment Leaks
..................................... 18 6.8 General Recordkeeping Requirements
....................................................20 7.0 QUALITATIVE AIR QUALITY ASSESSMENT
....................................................21 8.0 ENDANGERED SPECIES ACT
..........................................................................22 9.0 NATIONAL HISTORIC PRESERVATION ACT
..................................................23
Olson-FBIR Pad 12/29/11 pg. ii NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •
FIGURES Figure 1: Example of Maximum PTE from a Seven Well Pad
................................... 6 Figure 2: Example ofActual Production from a Seven Well Pad
.............................. 7 

## 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



# •



# • Olson-FBIR Pad 12/29/11 pg. iii NSR Synthetic Minor Permit Application Project#: WEP211324

# •

•

•



# • 1.0 INTRODUCTION 1.1. 

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

### y.. of the northeast 

### y.. Section 13, Township 150 North, Range 92 West, Mountrail County, on the FBIR in North Dakota. 

## 1.3. Site Description At the proposed Olson-FBIR Pad there will be seven 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 Mountrail County, North Dakota. The surrounding area is mainly used for agriculture and livestock grazing. The proposed pad's associated well names are: 1. Olson 12-1HX 2. Olson 12-1 HC 3. Olson 12-1HY 4. Olson 12-1HD 5. FBIR 13-24HC 6. FBIR 13-24HD 7. FBIR 13-24HZ 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.

Olson-FBIR Pad 12/29111 pg.1 NSR Synthetic Minor Permit Application Project#: WEP211324

# • 2.0 NARRATIVE DESCRIPTION This section of the application provides a detailed description of the operations at the Olson-FBIR Pad. For purposes of estimating emissions from this facility, the combined first twelve-month potential production from the seven 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. 7 - HeaterTreater/Separators 7 - Line-Heaters (0.75 MMBtu/hr max) 35 - Oil Production Tanks 1 - Gasoline Recycling Pump 14 - Produced Water Tanks 7 - Electric Lifting Units 7 - Oil and Gas Producing Wells 1 - Truck Loading Rack 1 - Manufactured Produced Gas Flare 7 - Diesel Engines 1 - Manufactured Enclosed Tank Vapor Combustor 

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

# • temperatures and low pressures allow for additional separation of the gas/oil/water phases from each other because ofdifferences in densities. The line-heater is fueled by onsite produced caSing head gas that is routed to the heater's combustion chamber. Propane may also be used as an alternative fuel if necessary. Following the heater treater the oil and water are routed to their separate storage tanks. The produced casing head gas is transferred from the two-phase separators to the sales gas pipeline. An 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 device. The stored oil is transported for sale via the truck loadout. Produced water is 

# • Olson-FBIR Pad 12/29/11 pg.2 NSR Synthetic Minor Permit Application Project #: WEP211324

# •
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. 

# •

•

Olson-FBIR Pad 12/29/11 pg.3 NSR Synthetic Minor Permit Application Project #: WEP211324 

# •

# • 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 ofthe application. As noted in Section 2.0 

### above, determination of potential emissions from the proposed facility has been approached in a very conservative fashion. The combined production rate for the pad assumes all ofthe wells start production simultaneously (represented in example Figure 1). With this assumption, the initial 3D-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. 

# •

•



# • Olson-FBIR Pad 12/29/11 pg.4 NSR Synthetic Minor Permit Application Project#: WEP211324

# • • 

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

# Example of Maximum PTE from a Seven Well Pad 6,000 • All 

### seven wells begin production 5,000 

### simuftaneous1v­ 

# •**~,ooo** 

## . CD 

# • 1,000 

# • 

# t lilt 

# . 

# ­ • Total Production from seven**w~nson** 

### Pad 

# • :1,000**~** 

# ---*..- ­

# ~~ ••••••••••• !
........ .

1,000



## o o 10 20 30 40 Month

Olson-FBIR Pad 12/29111 pg.5 NSR Synthetic Minor PermitApplication Project#: WEP211324

# • • • 

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

## Example ofActual Production From a Seven-Well Well Pad 3,500 " 6th and 7thwells begin production 3,000
2,500 Q 0. 

## Ii II 2,000 

# ! 

# l 5th well begins production

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

## -= 1,500 c -12-Month RollingAverage Oil Production limit o**~** 1,000

500



## o o 5 10 15 20 25 30 35 40 Month Olson-FBIR Pad 12/29111 pg.6 NSR Synthetic Minor PermitApplication Project #: WEP211324

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

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

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

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

## 3.2 Produced Casing Head Gas Emissions At the two-phase separator, +90% of all ofthe initial casing head gas is separated and sent to the gas sales pipeline. After the initial separation occurs, the leftover emulsified oil/gas/water is transferred to the three-phase heater treater. The heater treater then separates the residual gas from the oil and water. Due to the reduced pressure of the heater treater, the sales pipeline pressure is too high to overcome; therefore, the residual gas is routed to the onsite utility flare. Furthermore, if the gas sales pipeline Olson-FBIR Pad 12/29111 pg. 7 NSR SynthetiC Minor Pennit Application Project#: WEP211324 

# •

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

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

### JJJJ or 40 CFR 60 Subparts 1111 and 

### ZZZZemission limits as applicable. 

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

## 3.5 TruckLoading Emissions Oil sales and water pipelines are planned for this facility in the future; however, since the pipeline infrastructure has not yet been constructed, the facility is not anticipated to be hooked to the oil sales pipeline in the near future, and the produced oil and water will be trucked from the facility. The emissions associated with the truck loading operations will be estimated using daily production, AP-42 factors, and submerged fill loading without any control. 

## 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. 

# •

•

Olson-FBIR Pad 12/29/11 pg.8 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# •
4.0 EMISSIONSAND OPERATIONALLIMITS REQUESTS Oatoka-3 is requesting emissions and operational limits at the Tracy 15H Pad in order to obtain a synthetic minor status with regard to the NSR permitting programs. The federally enforceable permit conditions will allow Oakota-3 to operate the facility while emitting less than the PSOrritle V major source thresholds of250/100 

### 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 and HAP 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: 35.13 tons per year ofVOCs and 0.33 tons per year of HAPs. 

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

### JJJJ or 40 CFR 60 Subparts 

### 1111 and 

### Z:ZZZ, as applicable. 

# •

Olson-FBIR Pad 12/29/11 pg.9 NSR Synthetic Minor Pennit Application Project #: WEP211324 

# •

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

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

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

### PM, PM1Q, PM2.5 and N2

### 0 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 two

### phased 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 ExternalCombustion Unit Emissions No limits have been requested for the natural gas external combustion units 

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

# •

•



# • Olson-FBIR Pad 12/29/11 pg. 10 NSR Synthetic Minor Permit Application Project #: WEP211324

# • 5.5 TruckLoading Emissions No limits have been requested for the truck loading operations at the facility; therefore, the emissions estimate is equal to the uncontrolled potential to emit. 

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

# •

•

Olson-FBIR Pad 12/29111 pg. 11 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

## 6.0 PROPOSED MONITORINGAND RECORDKEEPING 

# •



# • As per the Application for Synthetic Minor Limit Request (Form SYNMIN), Page 1 (B), 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 StorageTanks The production storage tanks will have their flashing and standing/working/breathing vapors routed by a closed-vent system to equipment deSigned to capture the VOC and total HAP emissions generated at the facility for sale or other beneficial purposes, or an emissions control device that achieves a minimum of 98% destruction efficiency. Dakota-3 will follow the tank manufacturer's recommended maintenance schedule and procedures to ensure optimum performance. Furthermore, Dakota-3 will employ the following methods to ensure the tank vapors are efficiently being routed to the requested proposed device(s): a. Thief hatch covers will be weighted and properly seated; b. Pressure relief valves (PRV) will be set to release at a pressure that will ensure flashing, and standing/working/breathing losses are routed through a closed-vent system to equipment designed to capture the VOC and total HAP vapors. The vapors will be routed to equipment designed for sale or other beneficial purpose, or an emissions control device; and c. Periodic measurements of the peak pressure and vacuum values in the vapor recovery and control systems will be conducted to ensure that the pressure and vacuum relief set-points are not being exceeded (e.g., due to fouling or increased activity levels) resulting in venting and possible damage to equipment. 

### Monitoring Requirements: Dakota-3 will estimate the emissions from the production storage tanks by performing one ofthe following methods: a. Direct measurement of standing/working/breathing losses by sampling and lab analysis; b. EPA TANKS 4.0.9d to calculate standing/working/breathing losses; c. Direct measurement offlashing emissions by sampling and lab analysis; d. Process simulator such as PROMAX, HYSIM, HSYS using site-specific sampling and lab analysis to calculate flashing emissions in conjunction with EPA TANKS 4.0.9d to calculate standing/working/breathing losses; e. API E&P TANKS Software V2.0 using representative sampling and lab analysis to calculate standing/working/breathing losses and flashing emissions; or f. Other methods approved by EPA. 

# •

Olson-FBIR Pad 12129/11 pg. 12 NSR Synthetic Minor PermitApplication Project#: WEP211324 

# •

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

# • Dakota-3 will keep 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 facility will be controlled in one or more enclosed combustors and/or utility flares that are designed and operated to reduce the mass content of 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-outsystem 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.S °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.
Olson-FBIR Pad 12/29/11 

### pg. 13 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

### Monitoring Requirements: Oakota-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. Oakota-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 ofthe 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 ofall required monitoring ofthe control device operations. c. Records will be kept ofany instances in which any control device was bypassed or down in each calendar month, the reason for each incident, its duration, and the corrective actions taken or the preventative measures adopted to avoid such bypasses or downtimes. d. Records will be kept of the any exceedance of the operating parameters specified in the manufacturer or vendor guarantee or engineering analysis and selected for the required monitoring. The records will include the enclosed combustor's total operating time during the calendar month in which the exceedance occurred, the date, time and length of time that the parameters were exceeded, and the corrective actions taken or the preventative measures adopted to operate the facility within that operating parameter. e. Records will be kept of any instances in which the pilot flame is not present in the enclosed combustor or the utility flare, the date and times that the pilot was not present and the corrective actions taken orthe preventative measures adopted to increase the operating time 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 flame in the enclosed combustor or utility flare is not operational, the time period during which it was not operational, and the corrective measures taken. 

# •

Olson-FBIR Pad 12/29/11 pg.14 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • UNITED STATES ENVIRONMENTAL PROTECTION AGENCY Region 8 AirProgram FEDERAL MINORNEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

# oEPA CheckList
- Application for New Construction (FonnNEW) Please check all that apply to show how you are using this form

• Proposed Constructionofa New Facility 

## o Proposed Construction ofNew Equipment at anExisting Facility 

## o ProposedModification ofanExisting Facility 

## o Other
- Please Explain Use ofthis information request form is voluntary and not yet approved by the Office ofManagement aDd Budget 

# • The following is a check list ofthe type ofinformation that Region 8 will use toprocess information on your proposed project. While submittal ofthis form is 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 iscurrently under Office ofManagement and Budgetreview and these information request forms will be replaced/updated after that review is completed. Please submit information to following two entities: Minor NSR Permitting Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129 TheTribal Environmental Contact for the specific reservation: Ifyouneed assistance in identifying the appropriate Tribal Environmental Contact andaddress, pleasecontactthe EPA Region 8 Tribal AirCoordinator: Alexis North, EPA Region 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 Olson-FBIR Pad

3. Type ofOperation Oil andGas Production 4. Portable Source? 

# o Yes rgj No 5. Temporary Source? 

## 0 Yes rgj No 6. NAICS Code 213111 7. SIC Code 1311 8. Physical Address: 1001 17tn Street, Suite 1200 Denver, CO 80202 9. Reservation* FBIR 10. County* Mountrail 11a. Latitude* 47.81687 11b. Longitude* -102.39371 12a. Quarter Quarter Section* NWNE 12b. Section* 13 12c. Township* TISON 12d. Range* R92W 

# •

### FacilityName on the Permit N/A 

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

# I Date ofthePermit Action N/A 

# •

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 sectionofthe permit application is not applicable. This application is for a new facility for which no previous permit actions have been taken.


# •

•



# •

# •

•

•

• 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 atthe 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 VOC (or VOC and HAP) emissions in the vapors vented to the device by at least 98%. Dakota-3 will follow, for the utility flare, the manufacturer's written operating instructions, procedures and maintenance schedule to ensure good air pollution control practices for minimizing emissions. ' All vent lines, connections, fittings, valves, relief valves, or any other appurtenance employed to contain and collect vapors and transport them to the utility flare will be maintained and operated during any time the facility is operating. Olson-FBIR Pad 12/29111 pg,15 NSR Synthetic Minor Permit Application Project#: WEP211324

### The emergency utility flare will be: a. Designed and operated in accordance with the requirements of 40 CFR 60.18 and 40 CFR 63.11. b. Designed to have sufficient capacity to achieve at least a 98% destruction efficiency for hydrocarbon volumetric flow and BTU content routed to the device; c. Operated with a liquid knock-out system to condense any condensable vapors; d. Equipped with a thermocouple to detect the presence of a pilot flame with a minimum accuracy of ±2 percent of the temperature being monitored expressed in °c, or ±2.5 °C; e. Equipped with a recording device, such as a chart recorder or similar device, to document the presence of a flame; f. Equipped with an electronically controlled ignition system with a malfunction alarm and remote notification system ifthe pilot flame fails; g. Maintained in a leak-free condition; and h. Operated in a smokeless mode. Monitorinq 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. Recordkeepina 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 1212, 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. 

# •

•

•

Olson-FBIR Pad 12/29/11 pg.16 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

# • 6.6 TruckLoading The truck loading rack is designed for submerged filling of the tank trucks. This is standard operating procedure. i 

## I Monitoring Requirements: The monitoring requirements for truck loading will be estimating the monthly VOC, total 

# I HAP, and any single HAP emissions from the loadout operations using input parameters, equations, and emission factors from AP-42, Fifth Edition, Volume I, 

# I Chapter 5. I 

### Recordkeeping Reguirements: 

# t 

# •**~** 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, 

# I Dakota-3 will, at the end of each month, add the emissions for that month to the calculated emissions for all previous months since operations commenced, where applicable, and record the total. Thereafter, Dakota-3 will, at the end of each month, add the emissions for that month to the calculated emissions for the preceding eleven months and record a new twelve-month total. Dakota-3 will keep all input parameters and calculations used to determine the monthly emissions. 

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

# • a. At a minimum, Dakota-3 will detect and repair leaks at each tank thief hatch, centrifugal compressor vent, reciprocating compressor vent, instrument, meter, diaphragm, pressure relief device, dump arm, open-ended valve or line, vent line, flange, connection, fitting, or any other appurtenance employed to contain and collect vapors and transport them. b. Dakota-3 will make the first attempt to repair any leaking equipment within five days after the leak is detected. c. Any leaking equipment will be repaired as soon as practicable, but no later than 15 days after the leak is initially detected, unless the repair is technically infeasible without a facility shutdown. Such equipment will be repaired before the end of the first facility shutdown, after the leak is initially detected. Dakota-3 will make the first attempt to repair any leaking equipment within five days after the Olson-FBIR Pad 12/29/11 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 Requirements: 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 Requirements: Olson-FBIR Pad 12/29/11 pg.18 NSR Synthetic Minor Pennit Application Project#: WEP211324 

# •

# •

a. Dakota-3 will document and maintain a record of each leak detection inspection and repairs. b. All leak detection inspection records will include, at a minimum, the following information: 

### i. Date ofthe inspection; ii. All documentation and/or images produced in the inspection; iii. Findings ofthe inspection; iv. Any corrective action taken; and v. Inspectorfs name and signature. 

## 6.8 Genera) Recordkeeping Requirements 

# • Total VOC (or VOC, 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 

# I months and record a new twelve-month total. 

## J Dakota-3, when feasible, may use a Supervisory Control and Data Acquisition (SCADA) 

# I 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. 

# •

Olson-FBIR Pad 12129111 pg. 19 NSR Synthetic Minor Permit Application Project #: WEP211324 

# •

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

# •

•

•

Olson-FBIR 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 NOM 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 of such species. lES are considered to be those species recognized by the USFWS as listed or proposed species, and those designated as candidate lES under the ESA. Whether critical habitat for TES exists near the facility will first be assessed by consulting the USFWS North Dakota Ecological Service Field Office website 

# • (http://www.fws.gov/northdakotafieldoffice/index.htm) and noting the potential occurrence of each TES by county. Once the potential presence of a species is assessed, a look at whether any critical habitat exists in the vicinity of the facility will help determine the possibility of any impacts from the facility on TES. EPA will conduct an evaluation of the potential for TES impacts from the facility and consult, as appropriate, with USFWS regarding identification and mitigation of any impacts.



# •

Olson-FBIR Pad 12129111 pg.21 NSR Synthetic Minor Permit Application Project#: WEP211324 

# •

## 9.0 NATIONAL HISTORIC PRESERVATIONACT 

# •

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

# • Tribal offidals to identify any cultural resources that could be impacted by the facility and any needed mitigation measures for those impacts.



# •



# • Olson-FBIR Pad 12/29/11 pg.22 NSR Synthetic Minor Permit Application Project#: WEP211324

# • •

Facility Information

1 01son.FBlR Pad AssociatedWells: ,Olson 12·1HX, 12·1HC 12·1HY, 12·1HO, FBIR 13·24HC. 13.24HZ, 13·24HO Not Producing Yet nData BOPD**~** Decline Factor Adjusted BOPO Adjusted Produced Gas (t.IIscfd) 

### 22 .E!!. 0.505 27011 1880 RED = No input required. This is a calculated value.



# ... ..:;::.:::.;....__..._ml

on

, pIOCIucIIoIIlrI of011 pol'cloy\IIOPIlI.1NIHd 0\1thepnodIcIodIIIIt30...,.ofP'O'IucUon. [JIll IttIIe
....... 1IOPO to III procIucod 1111.. tile .....................f8ctor. tn..... tile .....PIoIodIllOtl ofIJIItho
... IttlCpICIIIdtoP'O'I- IIIIngtile .....................f8ct0r. 

# • •

Dakota-3 E&P Company, LLC Input Data GREEN 

### =Requires input

OlllCondell8ate Tlnk Data DHc:rlptlon Flash Gas Method: Procass Simulator**~"""'down** 

## ....Utoe"""""tho

### """"'prIMo....hIJII moIIIod. fTheocflbbl"""'dllllCl
......**_or~** 

# ........ a-on .""' Process Simulator Estirneted scflbbl 41.57

__ E&P Tlllk E_1onSu
.....ryOutput. Estimated Tank Vapors (scfd) 112.c.41.481!'h....tileMlIIIIIIIdICfdoIlInItWPOIllblood 0\1 tllelllllowlllCl:tdJlIIIodBOPO mulllpWbytiletcflIbbl........on Uno•• Lower Heating Value 2395.38 I

............. ESPT ••k**~Ion** IhrmrrIory Output. L-h-.a
...... (BIuIIdI ofllllkYlpOIlI. a-on MolecularWeight 41.99 IMoIocuIorwolgirtoftllellnltWPOIlIIn ,011liii0 pol',o...........Io(blHrlalo). a- on ESP Tonk**~Ion** SU""""!YOutput. VOC% 76.568**~_""hlfnICIIon** ofthellllkwpo'lJII(C3+', a- on ...._ ESPTook**E~** Output. VOC TPYIBOPD Emission Factor 0.649 on ............. ESP**Tlllk~** su.....ryOutput.(Iu""""!YOuIput
........ IIrIoor roIoIIo.. bIMMnTPV IIIId BOPD) HAP% HAP TPYIBOPD Emission Factor 0.718 0.006 woIgIrtfnlCllon oftllellnltwpor
.... a-on ........_ ESPTonk IhrmrrIory 0UIput.**~on""",,-** ESP**Tonk~** su.....ryOUlput.(Iu""""!YOuIput-.-roIoIIo
..hlpblMMnTPYIIIId BOPD) C02% 0.23% woIghIfnICIIon 01thelInItWIPOfIJII. a­ ""
........_ ESPT
..k**~Ion** SU""""IY0uIput. CH4% 1.59%**~""hlfnICIIonoftlle""kWlPOfIJll.** a-""

__**E&PT"'~** ........ry()ujput.**H~weight%** 0.16% ....ht_ntoftlleIlnkWlPOf""a-on ........_ ESP T
..kE_lonlhrmrrloryOulput.**H~moIe%** 0.20%**~molt_ntoftllellnkwpor lJII.a-on~ESPT**  ..**k~IonSumIlllllYOutput.** Enclosed Smokeless Combustor**~the** ............. 110 chrmetlle.........,nolo
......IonCOl'llllllwe. Control Destruction Efficiency 98%**~""'I** elllcloncy oflIlYoppIIcabIo_hit. ThIt It. tIad numblrINIHdon.....trolwe.

..... tf**.<4_~,~1WI~** II )1_ 11:**'11'~!** It'W(**,..",~~~**

# • 

# • nnuUUOakota_3 E&P Company, LLC Input Data GREEN =Requires Input RED

### =No input required. This is a caleulated value. Facility Infonnatlon Olson·FBIR Pad Associated Wells: Olson 12.1HX, 12.1HC 12.1HY. 12-1HD. FBIR 13.24HC, 13·24HZ.13·24HD

# [.~- .......

# ­ TreaterGal Data Description Btu/act 1814.20 BtuIocfof
........ po.**(F1OIII"'~"""po"lIj** MolecularWeight 31.69 A
.... moIoc.welghtoltho
......... po In
........... (F
............-"""po
.... l Specific Gravity 1.09 if_til**co_opocIfto~tII** ....... wt/gIIt, ....**'thoopoclfto~oItho** ......mpo. (F-**~"floldpo"lIl** Average MolecularWeiaht 31.69 (From..,_tIoId
........., VOC% 50.99%**WCwolghl_.oftho.....-po(llot.:WtIgh!!I..notlilllll'Ao~** (From..,_tIoIdg••""",II) HAP% 0.72% HAP IMIghifrIotIon01tho
.........a •. (!lot.: w.Ight'Ii. not MoII'IIoj. (F
...... ..,- """" _Iytloll C02% 0.770"10 CO2welghtfrlotlon01tho .......",.
..... (IIot.:w.Ight'l!., not

### "'101",. (From ..__ """...._Iytloll CH4% 21.422% CH
....lghtfrlotlonoltho
.............**(IIot.:WolgIoI'II.notlllolo'll~** (F................... """po
.. III H:zS weight % H,S ..lghlp"rconIoftho
.. ..... (F
...... "'

__ tIoIdv- • ....,., 0.000"10 H2S mole % 0.000"10 H,S ..... percontoltho.......",.
.. po. (F
...... ....--tIoIdpo."""'
.., Connected to &ales line UNtho dIop down IMIIUto ct.o.ltho .."
....pr\III
......1on controltvPI. ControVCapture EffICiency ",uIodtilP
......., allUlllld 1_captu",of
.... IIIInId, _1
.....1onoyofany.......,...._III (co
.........,.pIno.., .allyIII...

### ole,. 100% Treater Bumer{s) DescrIption .wbu"""I1IIIna Ior!hl '--_bul'Mlf.11n 1Ituh-. rlhlro""' mulllpll bulIIIII,odd!hlliDllllhullnputtoaolhlr. Hours ofOperation Totel Btu/In

Temperature Load Rate (bbVhr)



# • 5250000

50.00 180 Th'bul'MlflllllllroaaUlNldto

__ 1,710haunt ....._. 8780 Truck Loading Description Oil is hauled bytruck UN !hidraD down IMIIUtocIIooRtho 'DDIIlIIriIIIo01 ..... 1IIIfhod.1'o1 IIoold
.......... I !.ACT noIn_ut...... I
.."",olrod In Lin
..3D-35. Submel'lled loading: dedicated normal service 0.6 UN !hidIop down lilttilct.o.l!hliPP"'
........modo ofopellllon.The_lIotIonfIcIor
... lutallllllcdy bauIocIod b
..... on modo 01ope_•. IIIoIoIcWorwelghtolllnllWipO'"In
.......... AD
.......__ ............weIght.llahlncl

__ fIo.. ....-- Ell'T.n""
__ MolecularWeight 41.99 Vapor Prassure lUIWipO'

__ 01liquidIoIdod,_nelli_or_inch IIbIoIuII

## (pili'" no ... opecIftr:dtIt II
...........pIoao""",tilTobie 2o. TlUCk Laldlng bib. oIbulkllquldloldlclln FIhmIhd.Ifno ... opecIftr:dtItIe-a.IIII,
_ .. .....- ............**~.** 1.OId,.01liquid 1oIdIcI1n ..... pithour. Load Time (hrs) 2.30
1.00 Tht
.... ltlllooo 10 ....ut_ ....**(In~** IPnaumatic Pumps andContollenl (None) IGIycoI Dehydrator (None)


# •

# • • 

# •

FacUlty: OIson.FBIR Pad """'oclatedWells: !Olson 12·1HX. 12·1HC 12· 1HY. 12.1HD. FBIR 13-201HC.**13~4HZ,** 13·24HD

Oil/Condensate Tanks Casing Head Gas Treater Burner RICE Engine Truck Loadina Fuel Storalle Tank Pneumatic Pump Pneumatic Controllers Glycol Dehydrator HOx PM10 PM2.5 CO N/A NlA N/A NlA 4.23 0.26 0.26 23.03 2.25 0.17 0.11 1.89 30.44 0.18 0.18 50.26 N/A NlA N/A N/A N/A NlA N/A N/A N/A NlA N/A N/A N/A NIA N/A NlA N/A N/A N/A N/A

HAP 0.33 0.50 0.04 1.19E-Ol

0.21 Negligible

N/A N/A N/A 

# •

S02 N/A 0.00 0.01 1.45E-Ol

N/A N/A N/A N/A N/A 'Totals(TPY)

OIl/Condensate Tanks Casing Head Gas Treater Burner RICE Enoine Truck Loadina Fuel StorageTank Pneumatic Pump Pneumatic Controllers GlYCOl Dehvdrator ITotais (TPY) 

### , I



## I I VOC 1156.27 29.25 0.12 7.93 22.54 N9!llillible

N/A N/A N/A 1818.12

voc 35.13 29.25 0.12 7.93 22.54 Negligible

N/A N/A N/A 94.98 Uncontrolled Potential to Emit Criteria Pollutants HAP PM H2S 16.31 N/A N/A 0.50 0.26 NA 0.04 0.17 N/A 1.19E-Ol 0.18 N/A

0.21 N/A N/A N9!lliclible N/A N/A

NlA N/A N/A N/A N/A N/A N/A NlA N/A 

### , I 17.19 

### I I 36.93 

## , I 0.61 

### I I 0.61 

## II 0.61 

## II 75.18 

### I , 0.00 

### I I Allowable Potential to Emit Criteria PollutantsHOx PM PMl0 PM2.$ CO H2S 3.34 0.16 0.16 0.16 18.19 N/A 4.23 0.26 0.26 0.26 23.03 0.00 2.25 0.17 0.17 0.17 1.89 N/A 30.44 0.18 0.18 0.18 50.26 NlA NlA N/A NlA NlA NlA NlA N/A NlA N/A NlA N/A NlA N/A NlA NlA NlA N/A N/A NlA N/A NlA N/A N/A N/A N/A NlA N/A N/A N/A N/A 

## I I 1.20 

## I I 40.27 

## I I 0.76 

## I I 0.78 

## I I 0.76 

## I I 93.37 

## I I 0.00 

## I I HCHO Negligible

0.00 Negligible

0.12 Negligible

N/A Negligible Nellliclible Negligible 0.16 

### I I 0.12 j**S~** HCHO NIA N9!lliaible 0.00 0.00 0.01 Negligible 1.45E-Ol 0.12

N/A Negligible NlA NlA NIA Negligible N/A Negljgible N/A N9!lliglble 0.16 

## I I 0.12 

## I 

# IIDakota-3 E&P 

# Company, LLC II

Emission Summary

Emissions ofleed and lead compounds. fIuorid... sulfuric add mist. lotal reduced suIM. and reduced suIMcompounds alii assumed to be negiligable forupstream oil & go.operation. onthe FBIR.9590.15 9906.54

No FaclHIy: ptson-FBIRPad**~Hocl.tad** Will.: 

# II**D;k~ta~E&P** Co;pany,

# Lic

# II

Olson 12.1HX, 12·1HC 12· 1HY. 12·1HD. FBIR**13~HC.** 13·24HZ, 13·24HD

Potential To Emit Actual Greenhouse Gasesb Greenhouse Gasesb co2 CH. N20 CO2 CH. N20 OiVCondensale Tanks N/A 36.17 N/A 2467.71 0.00 0.05 Casing Head Gas 4138.65 12.29 0.00 4138.65 12.29 0.00 Treater Burner 2705.29 0.15 0.03 2705.29 0.15 0.03 RICE Engine 2.65E+02 0.40 0.08 2.65E+02 0.40 0.08 Truck loadino 0.07 0.47 NlA 0.07 0.47 N/A FuelStoraae Tank N/A N/A N/A N/A NlA N/A Pneumatic Pump N/A N/A NlA NlA N/A N/A Pneumatic Controllers N/A N/A NfA N/A NlA N/A GlYCOl Dehydrator NfA NlA NIA NfA NfA NfA 'Total. (!PY) 

### I , 7108.96 

### I I 49.48 

### I I 0.12 

### I I 957U8 

### I I 13.31 

## I I 0.16 

## I
GHG ..... EmiHlona(tpyl: 

# I 7158.56 

# I GHG .....emissions(tpy): C02S (tpy): 8183.80 C02.(tpy): Appllcabkttothe Tailoring RuIs?:



# .



# • • • 

# • HydrollUOl'OCllrtl"". (HFCs), _""""""",,no (PFes). al'd SuWur H

__ (SF6) eml••1ons .nonot."....edfrom O&G prtJducllon

__.

# • • • 

# •

Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY.12-1HD. FBIR 13-24HC.13-24HZ. 13-24HD 

# Oakota-3 E&P Company, LLC

Tanks

Oil Production! 2705 BOPO Flare Gas Volume! 112,441 scI/day Lower Heating Value! 2395.38 Btu/scf

Molecular Weight! 41.99 Ibflb-mole! VOG wt Fraction! 76.57% VOG Emission Facto1 0.649 tprtbopd ! HAPs: Benzene wt Fraction 0.0186% I Toluene wt Fraction 0.0132% I E-Benzene wt Fraction 0.0018% I Xylene wt Fraction 0.0109% n-Hexane wt Fraction 0.6143% 2.2.4-Trimethylpentaner---::-:::=:::-_., wt Fraction! 0.0587% HAP Emission Factor! 0.006 tpy/bop<! 

### ! G02 wt Fraction! 0.23% GH4 wt Fraction! 1.5K::J

Conlrolled emissions are calculated based on a**~destruction** efficiency 01 the vac gas.**~"<"'fq~f)KJ,"Mjl4 4~1~~·~-":.-"""'1'_~~"'ii4~~**  ,ffi llfJ 1$,,1 "'!l:lII**.¢J~~~!!'/.!I'J,'ilI"'il~\iI'~_~~4ii",*,** \\IlI'i\II# ", tit**"1~**

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

# I Tanks Olson-FBIR Pad Associated Wells: Olson 12·1HX, 12-1HC 12·1HY. 12·1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

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

## I 0.649 TPV VOCIBOPO 

## I x 

### 12704.87 BOPO x 

## I ORE 0% 

### 1 1756• 27 TPvl Controlled VOCs (Allowable):

sing E&P Tanks Run: 

## I 0.649 TPV VOC/BOPO 

## I x 

### I 2704.87 BOPO x 

### I ORE 98% 35.13 TPvl Uncontrolled HAPs (PTE): Using E&P Tanks Run: Benzene 4,685 scflhr E-Benzene 4,685 scflhr

Toluene 4,685 scflhr n·Hexane 4,685 scflhr

Xylene 4,685 scflhr 2.2.4.Trlmethylpentane 4,685 scflhr x x x x x x 1/379 scf/lb-mole 1/379scfl1b-mole 1/379 scfllb-mole 1f379 scfflb·mole 11379 scfflb-mole 1/379 scfllb-mole x x x x x x 41.99 41.99 41.99 41.99 41.99 41.99 lb11b·mol IbIIb·mol Ibllb-mol Ibllb-mol IbIIb·mol Ibllb-mol x x x x x x

### ~**~** 

## ..gg**~ ~** **~ ~**  x x x x x x ORE 0% 

### " 0.101blhr 0",(, " 0.01 Iblhr 0% " 0.071blhr 0% = 3.191blhr 0% = 0.061b1hr 0% " 0.301blhr Uncontrolled TOTAL HAPS (TPV) 

# .. = " 

# .. .. " " 

## I TPY 0.42 0.04 0.30 13.97 0.25 1.33 16.31 Controlled HAPs (Allowable): Benzene 4,685 scflhr E·Benzene 4685 scflhr

Toluene 4,685 scflhr n·Hexane 4,685 scflhr

Xylene 4,685 scflhr 2.2.4.Trimetl1ylpenlane 4,685 scflhr x x x x x x 1/379 scf/lb-mole 1 f379 scfl1b-mole 1f379 scf/lb-mole 11379 scfllb-mole 11379 scfl1b·mole 1/379 scfllb-moIe x x x x x x 41.99 41.99 41.99 41.99 41.99 41.99 Ibllb-mol Ibllb-mol IbIIb·moI Ibllb-moI Ibllb-mol Ibllb-mol x x x x x x**~** 1 0•

02% 

## ..gg**~ ~** **~ ~**  x x x x x )( 98% = 0.00 Iblhr 98% " O.OOlblhr 98% " O.OOlblhr 98% " 0.061b1hr 98% " 0.00 Iblhr 98% " 0.01 Iblhr Controlled TOTAL HAPS (TPy) 

# .. .. 

# .. .. .. 

# ..

= 

## I 0.01 0.00 0.01 0.28 0.00 0.03 I I 0.33 I

--­

# • • • 

# •

Oakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson**12-1H~** 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

### Tanks Uncontrolled NOx: NOlI:' 0 scf/hr x 

# , 2,395 Blulscf , 0.00 Ib/hr x

x 1 MMBlul1.000.000 Btu 8760 hr!l!; x X 

### I 0.068 IblMMBtu , 

## I 1 10n/2000 Ib 0.00 0.00 Ib/hr 

### I 

## TPYI NOx Created by Combustion (Actual) NOx:, 4,885 set/hr x 

## I 2,395 Blulscf

## I
0.76 IbIIlr x

x 1 MMBlul1.000.000 Blu 8760 hr/yr x X 

### I 0.068 IbIMMBtu , 

# , 1t0n/2000 Ib 0.76 3.34 Ib/hr 

### I IPY , Uncontrolled PM:
PM:' 0 scf/hr x 

## I 7.6 1b/1.000.000 set 0.00 IbIIlr 0.00 Ib/hr x 8760 hr!l!; x 1 lonI2000 Ib 0.00 TPY PM Created byCombustion (Actual)
PM:l 4,885 set/hr x 

## I 7.6 0.04 Ib/1.000.000 sef Ib/hr x 8760**hr/~** 0.04

x Ib/hr 1 lonI2OOO Ib 0.16 TPY**'",,""'}'~'.,.,'** /t,MJIi) <1:;

_______""",

__""",,,,,,,,,...,.....,.

_____ •

____•

_______________**it\ltG_"I,~~!'Il'II~~mfL9:11:I,W)ltf$li#i<#AA, ~~~u,.,'It;~~.""?_-.** 

# • • 

# • 

# • Oakota-3 E&P Company, LLC

Tanks Uncontrolled CO: 

### co:! 0 scflhr x 

### ! 2,395 0.00 Btulscfl Iblhr x
x 1 MMBlu/1,OOO.OOO Btu**8760hr~** x 

## I x 

### I 0.370 IbIMMBIu 

### I
1tonl2000 Ib 0.00 0.00 Iblhr 

### I
TPV 

## I
CO Created by Combustion (Actual) 

### co:! 4,685 scflhr x 

### I 2,395 4.15 Btu/sci

### I
Iblhr x
x 1MMBhM'1.000,OOO Btu 8760 hr/l" _ I x 

### I x 

### I 0.370 IblMMBtu 

### I
1tonl2000 Ib 4.15 

### I 18.19 Iblhr 

### I
TPY 

### I "NOx, S02. and CO emission factOB are from AP-42 Table 13.5-1 (Emission Factors for Flare Operations)
. Olson·FBIR Pad Associated Wells; Olson 12·1HX,12·1HC 12·1HY,12·1HD, FBIR 13-24HC, 13·24HZ, 13·24HD

# • 

# • • •

Dakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson 12·1HX. 12·1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

### Tanks REGULATED GREENHOUSE GAS EMISSIONSb Uncombusted CO2: C02:! 4,685 scflhr 

### I x 

### 111379 scfllb-mole

### I x 1.20 41.99 Ibllb-molel Iblhr x wt x ! 0.23% 

## I
8760**hr~** x 

## I ORE x 0% 1tonl2OOO Ib 1.20 5.24 Iblhr TPY C02 Created byCombustion (Actual) C02:! 4,685 scflhr x '120,000.0 Ibl1,OOO,OOO scf ! 562.21 Iblhr 

### I x 8760 hrfyr 562.21 Iblhr !
x ! 1tonl2OO0lt'l 

### I (2462.47 TPY 

### :J

..",

__**~~,l(>!** ____ ,**d"'~"(f'<i?'!,,~,J>\E '~~,~~**  UP,',**oI~_,.WM "",_'**  _____________

# • 

# • • • Dakota-3 E&P Company, LLC
[**~n~** Uncontrolled CH4: wt ORE CH4:1 4,685 scflhr x 11/379scfnb-mole 1 x 8.26 41.99 Iblhr Ibllb-moIel

x x 11.59% 1
8760 hr!x!: x 

### 1 x 0%
1tonl2000 Ib 8.26 36.17 Iblhr TPY Controlled CH4: (Actual)
CH4:1 4,685 scf/hr x 111379 scfnb-mole 1 x 0.17 41.99 Iblhr Ibllb-mole1

x wt% x 

### 1 1

.59% 1
8760**hrl~::J** x 1 ORE x 98% 1 10012000 Ib 0.17 0.72 Iblhr TPY Olson-FBIR Pad Associated Wells: Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD

# • • • 

# •

C02 and N20 emission factors are from AP-42 Table 1.4-2 (Emission Factors lor Natural Gas Combustion). 

# Dakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson 12-1HX. 12-1HC 12-1HY.12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

### Tanks Uncontrolled N20:
CH4:! 4.68l! scf/hr ! x 11/379 scfllb.mole ! x 

## I 0.00 

### I 41.99 1Mb-mole! Iblhr 

## I x 

## I wt% x 10.00% !
8760 hr/:t! 

## I x 

## I ORE x 1 0% 1 tonl2000 Ib 

### I 

## I =

= 

### I 

## I 0.00 0.00 Ib/hr TPY ! 

## I N20 Created byCombustion:
CH4:1 4,88l! scf/hr 

## I x 

## I 2.3 Ib/1,000,000 sef 

## I 0.01 Ib/hr 

## I x 

## I = 

### I 

## I 8760 hrl:t! 

## I 0.01 Iblhr 

## I

x 

## I 1 tonl2OOO Ib 

## I = 

## I 0.0l! TPY 

## I

# • • 

# • • Oakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

## Casing Head Gas

Flare Gas VOlumel -7,832 sctlhr ](Takes into account the 10% of the lotal produced gas volume that is not being sold.) Lower Healing**Valuerl--1~8:'::1-:4.":2:----:B:'!t-ul:-scf-:-"'"I** Avg. Molecular Weight! 3Ul9 1Mb-mole I VOC wt fractionr 50.99% HAP wt fraeliol 1 0.72% 0.06% 0.01% 0.01% 0.68% 0.05% Benzene wt fraction 1 E-Benzenewt fraetion 1 Toluene wt fraetio 1 n-Hexane wt fraetio 1

Xylene wt fractio 1 2.2.4-Trimethylpentane
...._-;;:-:;;;-;;;-_--, wt fractionl 0.00% C02wt fraction! 0.77% -:::1 CH4 wt fractionl- 21.42% Hours of Flaring**Io~** 8760 hoursl),!" PTE:IL _________ Control Efflicie 98% ORE

# • •

-------- 

# Dakota-3 E&P Company, LLC 

# •

Olson-FBIR Pad Associated Wells: Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC.13-24HZ.13-24HD 

### Casing Head Gas CRITERIA POLLUTANT EMISSIONS8 Controlled VOCs (PTE): wt% Control % voe:1 7,832 scflhr x 11/379 scf/lb-mole x 6.68 131.6925 IbIIlr 1Mb-mole 1

x x 8760**hr/~** 50.99%1 x 1 98% 1

x 11 tonl2OO0 Ib 6.68 29.25 Ib/hr TPY Controlled VOCs (Allowable): wt%**ConllOl·~** voe:1 7,832 scflhr x 11/379 scfllb-mole x 6.68 131.6925 IbIIlr 1Mb-mole 1

x x 8760**hr~** 50.99%1 x 1 98% 1

x 11 tonl2OOO Ib 6.68 29.25 Iblhr TPY 

# •

jItf,.,.QIll**~._!~#~~r!t!" 4¥,'~** **l,I!'~~"if Wl\1~~"4~i'I'4iii"'''''1W"** **","tI'M"~~'"**

# • • 

# • • Dakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson 12-1HX.12-1HC 12-1HY.12-1HD. FBIR 13-24HC.13-24HZ. 13-24HD 

## Casing Head Gas
Controlled HAPs (PTE): Using E&P Tanks Run: Benzene 7,832 scf/hr E-Benzene 7,832 scflhr

Toluene 7,832 scflhr n-Hexane 7,832 scflhr

Xyfene 7,832 scflhr 2.2,4-Trimethyfpentane 7832 scf/hr Formaldehyde 7,832 scflhr x x x x x x 11379 scfllb-mole 11379 scfl1b-mole 1/379 scfl1b-mole 1/379scf/lb-mole 11379 scfl1b-mole 11379 scfllb-mole 7.50E"()2 IblMMscf 0.12 x x x x x x Iblhr 31.6925 31.6925 31.6925 31.6925 31.6925 31.6925

x Ibllb-mol x IbII!)..mol x Ibllb-mol x Ibllb-mol x Ibllb-mol x Ibllb-mol x 8760**hr~** wI% Control % 0.06% x 98% 0.01% x 98% 0.07% x 98% 0.68% x 98% 0.05% x 98% 0.00% x 98%

x 

### 11 lonl2OO0 Ib 0.01 Iblhr 

### ,. 0.00 Iblhr 0.01 Iblhr 

### • 0.09 Iblhr 0.01 Iblhr 0.00 Iblhr O.OOlblhr 0.50 TPY TPY 0.03 0.01 0.04 0.39 0.03 0.00 0.00
Controlled HAPs (Allowable): Using E&P Tanks Run: wI% Control % TPY Benzene 7,832 scflhr x 11379 scfllb-mole x 31.6925 Ibllb-mol x 0.06% x 98% 0.01 Ib/hr 0.03 E-Benzene 7,832 scflhr x 1/379scfllb-mole x 31.6925 Ibllb-mol x 0.01% x 98% 0.00 Iblhr 0.01

Toluene 7,832 scf/hr x 1/379scfllb-mole x 31.6925 IbII!)..mol x 0.07% x 98% 0.01 Iblhr 0.04 n-Hexane 7,832 scflhr x 1/379 scfllb-mole x 31.6925 Ibllb-mol x 0.68% x 98% 0.09 Ib/hr 0.39

Xyfene 7,832 scflhr x 1/379scfllb-mole x 31.6925 Ibllb-mol x 0.05% x 98% 0.01 Iblhr 0.03 2.2,4·Trimelhyfpenlane 7,832 scf/hr x 1/379 scfllb-mole x 31.6925 Ibllb-mol x 0.00% x 98% 0.00 Iblhr 0.00 Formaldehyde 7,832 scflhr x 7.50E"()2 IblMMscf 0.12 x Iblhr 1000000 x scflMMscf 8760 hrlyr x 11 lonl2OO0 Ib 0.00 Iblhr**I_O~TELJ** 0.00

# • • • 

# •
[ Dakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson 12-1HX.12-1HC 12-1HY.12-1HD. FBIR 13-24HC. 13-24HZ.13-24HD 

### [ Casing Head Gas
Uncontrolled NOx (PTE): NOx:! 7.832 setlhr x 

## I 1,814 Btu/set 0.911blhr x

x 1 Mmblul1.000.000 Btu 8760 hr!l! x x 0.068 IblMMBtu 

### I
1 ton/2000 Ib 0.91 4.23 Iblhr TPV NOx Created by Combustion (Actual): Nox:1 1,832 setlhr x 

### I 1,814 Btu/set 0.91Ib/hr x

x 1 Mmblul1.000.000 Btu 8760**hr~** x x 0.068 IblMMBtu 

### I
1ton/2000 Ib 0.91 4.23 Iblhr TPV Controlled H2S (PTE): H

2s:1 1.832 scflhr x 111379 scfnl>-mole x 0.00 1 31.6925 Ibnb-moie 1 x Iblhr x 8760**h~** wt"4 Control % 0.00%1 x 1 98% 1

x 11 tonf2000 Ib 0.00 0.00 Iblhr TPV Controlled H2S (Actual):**H~:I** 1.832 setlhr x 11/379 scfllb·mole x 0.00 1 31.6925**Ib~b-mole** 1 x Iblhr 

### n I x n_8760 hrlyr 

### nl wt% Control % 0.00%1 x 1 98% 1

x 

### li!i:nI2OOO Ib 0.00 0.00 Ib/hr TPV

# • • • 

# • Dakota-3 E&P Company, LLC 

# I
Olson-FBIR Pad Associated Wells: Olson 12-1HX. 12-1HC 12-1HY.12-1HD. FBIR 13·24HC. 13-24HZ.13-24HD 

### Casing Head Gas
S02 Created by Combustion (PTE): 502

### 1 7.832 scflhr x 111379 sctnb-mole x 0.00 1 31.6925 Iblhr Ibnb-mole 

### I

x x 8760 hrlyr wt% Control % 0.00%1 x 

## I 98% 

## I

x [!1OO!2OO0 16­ 0.00 0.00 lbih!]
TPY S02 Created by Combustion (Actual): wt% Control % 5021 - 7.832 scflhr:J x 11/379 scMb-mole x 0.00 1 31.6925 Iblhr Ibnb-mole 1

x x 8760 hrlyr 0.00""'1 x 

### 1 98% 

### I

x 11 10nl2OOO Ib] 0.00 0.00 Iblhr TPY CO Created by Combustion (PTE): cO:1 

### t;m- nSCflhr] x I 1.814 Btu/sef I x 1Mmblu/1.000.000 Btu x 0.370 IblMMBlu 

### I 5.26 Iblhr] 5.26 Iblhi-::1 x 8760 hr/yr x 1tonl2OOO Ib 23.03 TPY 

### nJ CO Created by Combustion (Actual): cO:1 -7,832-------salhr:::J x 1 1.814 Btu/scf I 5.26 Iblhr x
x 1MmbIul1.000,OOO Btu 8760 hrlyr -::1 x x O,370lblMMBtu 

### I
110nl2OOO Ib 5.26 23.03 Iblhr 

### J TPV:J

# • • • •

Dakota-3 E&P Company, LLC Olson·FBIR Pad Associated Wells: Olson 12·1HX. 12·1HC 12·1HY. 12·1HD. FBIR 13·24HC. 13-24HZ. 13·24HD 

### Casing Head Gas
PM Created by Combustion (PTE): PM:I 7,832 scflhr x 

### I 7.6 Ibf',000,000 scf O.06lb/hr x 8760**hr~** 0.06

x Iblhr

, ton12000 Ib 0.26 TPY PM Created byCombustion (Actual): PM:I 7,832 scflhr x 

### I 7.8 Ibt1 ,000,000 sef 0.06 Iblhr x 8760**hr~** 0.06

x Iblhr
1ton/2000 Ib 0.28 TPY ·NOx. S02. PM. & CO emission factors are from AP42 Table 13.5-1 and Table 1.4-2 (Emission Factors for Flare Operations and Natural Gas Combustion).**~~~~-~~""''''~'_** "x,**~O;,** 4MI**~"'~"""~"l',****"'!""~~*""'''''',,<))!I!!U4.,;''****1\(_i'!"'1l"P~~~'~"~'>M'>#'''n** ,**:""'!'I'~IMf** _.,_____________•

# • 

# • 

# • • Oakota-3 E&P Company, LLC Olson-FBIR Pad Associated Wells: Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

# r Casing Head Gas 

# r- REGULATED GREENHOUSE GAS EMISSIONSb C02 (PTE): C02 Entrained In the Produced Gas: Control % C02:' .7;832

### ·_-seJ?hi:J x !11379 sctnb-mole x 

### 1 31.6925 Ibnb-mole 

### 1 x 0.77%1 x 

### I 98% 

### I 5.04 Ibfhr 

### 1 5.04 Ibfhr x 8760 hr!yr x 1110nl2OOO fb 

## :J 22.07 TPYl C02 Created byCombustion: C02:! 7,832 scflhr x 1120,000.0 Jbl1.000.000 scf I 939.8616Jhi 939.86 Iblhr x 8760 hr!yr :;J x ,-110012000 It:i 4116.58 TPY ] Total C02 Emitted (PTE):I 4138.65 TPY

# • • • •

Dakota-3 E&P Company, LLC

C02 (Actual): C02 Entrained In the Produced Gas: wt% Control % C02:! 7.832Sdlhr x [i7379Sdh6:moD x !**31.692~rriOie** I x 0.77%1 x 

### 1 98% 

### 1 

## r 5.04 Iblhr 

### 004 Ib/hr x 8760 hriyr x (!1on/2000 Ib 22.07 TPY--I C02 Created by Combustion: C02:! 7,832 scflhr _ul x 1120.000.0 1f)11.000.000scf 939.86 Ib/hr r:::J39-86 Ib/hr x 8760 hriyr uJ x 

### 1 ----rtOnI2OO0 If) 411&.58 fPY Total C02 Emitted (Allowable):! 4138.65 TPV**~~~~~-~~~~~~~~~~--~~~---------,** Olson·FBIR Pad Associated Wells: Olson 12·1HX. 12·1HC 12·1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13·24HD 

### Casing Head Gas

Controlled CH4 (PTE): CH4:1 7.832 scflhr x 111379 scf/lb-mole x 2.81 1 31.6925 Ib/hr Ib/lb-mole 

### I

x x 8760 hriyr wt% Control % 21.42%1 x 

## I 98% 

## I

x 11 ton12oo0 Ib 2.81 12.29 Ib/hr TPY Controlled CH4 (Actual):
CH4:1 7.832 scflhr x 111379 scfl1b-mole x 2.81 

### I 31.6925 Ib/hr Ibl1b-mole 

## I

x x 8760**hr~** wt% Control % 21.42%1 x 1 98% 

### I

x ,1 tonl2Ooo Ib 2.81 12.29 Ib/hr TPY

# • • 

# • • CO Oakota-3 E&P Company, LLC 

# I Casing Head Gas

0 N20 Created by Combustion (PTE):
N20:! 7,832 scflhr x ! 2.2 Ib/1.000.000 scf 

## I 1.72E.o2 Iblhr x 8760 hr!f !1.72E.o2 Iblhr

x 1tonl2OOO Ib 

## I 4.31E.o3 TPY N20 Created byCombustion (Actual): 

# .­ N20:! 7,832 scflhr x 

## I 2.2 Ib/1,OOO.OOO scf [j:fiE.o2 lbihr

__

### l x 

### I _**8760hr~** __ 

## I 1.72E.o2 Iblhr

x 

### L 1lonl2OO0 Ib
_ ! 4.31E.o3 TPY Olson-FBIR Pad Assodated Wells: Olson 12·1HX. 12-1HC 12·1HY. 12·1HD. FBIR 13·24HC. 13-24HZ. 13-24HD

he02 and N20 emission factors arefrom AP-42 Table 1.4-2 (Emission Factors for Natural Gas Combustion)
.

# • 

# • • •

Dakota-3 E&P Company, LLC 

# I

Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 

## Heater Treater Burnera

Burner Rating I 5,250,000 Btulhr !Thls burner rating reflects the combined size ofall ofthe proposed heater treater burners at the facility.
NOll:[ 0.10 IblMMBlu x 5.25 MMBlulhr I :: 0.515 Iblhr CO:S147 Iblhr x 8.760 hr!yr x

# '1 ton 12000 Ib , = 2.254 TPY
co:, 0:08 IblMMB!i[l x 5.25 MMBtulhr , 0.432 Iblhr 0.43 Iblhr x 8.760 hr/yr )( 

### I 1ton 12000 Ib , 1.894 TPY
s02:15.88E-04 IblMMBIu x 5.25 MMBtUlhi', CO.OO3 Iblhr 13.09E-03 Ib/hr::J x 8.760 hr!yr x I 1ton 12000 Ib I" 0.014 TPY
PM:, 0.01 16IMMBtu x 5.25 MMBtulhr I ( 0.039 Iblhr**~lblhr=:J** x 8,760 hrlyr x , 1Ion 12000 Ib I 

# r 0.171 TPY

# • • • • Oakota-3 E&P Company, LLC

Heater Treater Burner a

voc;, 0.01 IblMMBtu )( 5.25 MMBiU7!ifl i.f.lI28l6lhr:J 0.03 Iblhr )( 8,760 hriyr )( I 1 ton f2000 Ib 

### I 

# r 0.124 TPY::J HAP;I O.0021b/MMBlu:J )( 5.25 MMBtufhr 

## I 0.010 Ibfhr 19.**7~~-53** Iblhr )(**~,760 hr~**  )( 11 tonf20OOlbl = 0.043 TPY
c021117.647 IbfMMBtu )( 5.25 MMBtufhr 

## I 617.647 Ibfhr rn.18E+02 Ibfhr )( 8,760 hrlyr )( Utonf2000lbj 

### I 2,705.294 TPY Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY. 12-1HD, FBIR 13-24HC, 13-24HZ. 13-24HD

# • • • 

# •

"NOl(, 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 ofSubpart W). CH4:1 0.007 Ib/MMBtu 13.47E-02 Iblhr 

# Oakota-3 E&P**Compan~,** 

# LLC
• Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY, 12-1HO, FBIR 13-24HC, 13-24HZ, 13-24HO 

## Heater Treater Burnera

x 5.25 MMBtulhr 

### I
x 8,760 hrlyr 

## I x 11 lon/2000lbl = 0.035 Iblhr 0.152 

## TPY

H20:1 0.001 IblMMBtu x CS:25 MMBtWfif] 0.007 Iblhr 

### J**16~E:.o3** Iblhf 

### :::;J x 8,760 hr'i x 11 Ion 1200016 I r::::p:!3O 

### rpv U

2.25 NOxTPY 1.89 COTPY o.or--S52-TPY 0.17 -PMTPY 0.12 VOC TPY 'I C 0.04 HAP TPY ul 2705.29 C02 TPY 0.15 CH4 TPY**~J'I!.";.rRIO\."lm~~~"!I"~** •. *6 A 4 ..**i(IIIMil"~ft""''''** ______ 0.03 N20TPY

# • • • 

# • Oakota-3 E&P Com LLC
Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 

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

### I x 

# I 0.60 

# I x 

# I 2.30 

# I x 

# I 41.99 

# I I 

# I 510.00 

# I = 

# I 1.42

LL Truck Load Load Time Total Gas Ibl1 ,000 gal Rate bbVhr hrs gallbbl Emissions Ib/hr 1.42 

### I x 

# I 180.00 

# I I 

# I 1.00 

# I x 

# I 42.00 

# I=

# I 10.74 

# I LL Annual Emissions Uncontrolled Ib/1.000 gal**bbll~ ~a"bbl**  Ib/ton TPY**C3+VOCt~** 1.42 

### I x 

# I 9872n.88 

# I x 

# I 42.00 

# I I 

# I 2000.00 

# I =

# I 29.44 

# I I 22.54 ! 

## vae Emissions Uncontrolled Control % 

### TPY 22.54 

### I 

# I 0% 

# I I 1.00 

# I L22.54]



### =-==

# • 

# • • •

=­ 

### LL Annual Emissions Uncontrolled Ib/1,000 gal bbl/yr aallbbl Iblton TPY HAPstov 1.42 

### I x 

### I 987277.88 

### I x 

# I 42.00 

# I I 

# I 2000.00 

# I 

# =I 29.44 

# I I 0.21 HAPs Emissions Uncontrolled Control % TPY 0.21 

### I 0% 1.00 0.21 

# I I I 1 1 1 

### LL Annual Emissions Uncontrolled Ib/1 ,000 gal bbl/yr gaVbbl Iblton TPY C02tov 1.42 

### I x 

# I 987277.881 x 

# I 42.00 1 I 

# I 2000.00 1 

# =I 29.44 

# I I 0.07 CO2 Emissions Uncontrolled Control % TPY 0.07 

### I 0% 1.00 0.07 1 1 1 

# I I I LL Annual Emissions Uncontrolled Ib/1,OOO lal bbVyr aallbbl Iblton TPY CH4tpy 1.42 

### I x 

### I 987277.88 

### I x 

# I 42.00 1 I 

# I 2000.00 1 

# =1 29.44 

# I I 0.47 CH4 Emissions Uncontrolled Control % TPY 0.47 

### I I 0% 

### I I 1.00 

### I I 0.47 

### I

# Oakota-3 E&P Company, LLC 

# I II RICE Input Data 

# !

Combined Diesel Engines Description Hours of Operation 8760 

### IlEngintlI_umedto operata8,788houri peryear. Maximum HP Rating 1925 NOxglhp-hr 1.49E+00 IMinufacturerGUlrantee (40 CFR63 Subpart.requlrament1l),_ AttachmentF CO a/hp..hr 2.61E+OO IMInUtacturerGUlrlntee (40CFR

### s3 Subpart

### 1I11equ1rementa1-AttachmentF S02gJhp..hr 4.52E-06 IAfI.42Tible 303·1 PM !l/hp..hr 4.85E-06 

### 1Af'.42Tible 3.3-1 

### lVoc a/hp..hr 1.42E-01 ....nuflcturerGuarentee (40CFR63 SubpartIII requlmnenta),_ AttachmentF HAP glbh-hr 1.02E·06 IlAP-42 Table303·1 C02 glbh-hr 2.54E-03 

### 1IAf'.42Table 3.3-1 CH4 glbh-hr 2.10E-02 

## 140CFR98 Subp.rtC,TableCo2 N20 !l/hp-hr 4.20E-03 1140 CFR118Subp.rtC,Tlble Co2 Recycle Pump Description Hours ofOperation 8760 IlEnginel,_umedto operata 8,780 hOUri peryear. Maximum HP Rating 56 IlManufacturer's maximum hp I'IlIng. NOxg/hp-hr 4.99E+OO IAfI.42Tlble3.3-1 CO !l/hp..hr 3.1SE+OO 

### 11Af'.42Tible 3.3-1 S02g/hp..hr 2.S8E·01 

### 1IAf'.42Tlble 3.3-1 PM glhp..hr 3.27E-01 

### 1Af'.42Tible3.3-1 

### lVoc g/hp-hr 9.80E+OO 

### 1Af'.42Tible 3.3-1 HAP glhp-hr 2.20E-01 IAfI.42Tlble 3.3-1 C02Q1bh-hr 4.90E+02 

### 0Af'.42Tible 3.3-1 CH4 alhp..hr 2.10E-02 I4OCFRIIBSubplrlC,TableCo2 N20 glhp-hr 4.20E-03 1140 CFRIIBSubpertC,TableCo2 

# • • • 

# •

# • • • 

# •

Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 

# Oakota-3 E&P Company, LLC

Reciprocating Engine Emissions

ENGINE #1 1925:1 MAX HP .t!Q& I 1.49E+GlfijlHP-HRI x 1925 HP x 11Ib/453.&arams 6.33E+OO Iblhr x 8780 hr!f; x [!ion/2000lbl 

### = 12.77E+01 NOxTPY I**~** 

### I 2.1I1E+OO g/Hp-HRI x 1925 HP x 11 Ib'453.6**~rams** 1.11E+01 Iblhr x 8780**hr~** x 1ton'2000lbl 4.8&E+01 co TPY**~** 4.52E-OII**g/Hp~HR]** x 1925 HP x 11 Ib 1453.&**~rams** = 1.92E-05 Iblhr x 8780**hr~** x 1ton 12000lb1 

### = 8.40E-OS 502TPY eM.;. 4.85E-OII gniP-HRI )( 1925 HP )( 11 Ib 1453.&**~rams** 

### • 2.CI6E-05 Iblhr )( 8780**r~** x 1ton12000lbl = 9.02E-05 PM TPY**~** U2E-01 g!HP-HRI x 1925 HP x 11 Ib 1453.6**~rams** 1I.02E-01 Iblhr x 8780**r~** x 1ton 12000lb1 2.ME+OO VOC TPV !:t!fi 1.02E-OII g!HP-HR I x 1925 HP x 11 Ib 1453'&l!rams ...33E-OII Iblhr x 8780**hr~** x 1ton 12000Ibi 1.90E-OS HCHO TPY QQ.Z;. 2.ME-03 gniP-HRI x 1925IHP x 11 Ib 1453.&arams 1.08E-02 Iblhr x 8780**hr~** x 1ton I 2000lb

## I 4.71E-02 CO2 CH4: I**2.10~g?HP:HR]** x 1925 HP )( 11 Ib 1453.6**~rams** 8.91E-02 Ib/hr x 8780 hr!l!; x 1ton/2000lbl 3.90E-01 CH4 H2Q: I ".20E:cJa !!!AP:ARI )( 11925 HP x 11 Ib 1453.& grams 1.76E-02 Iblhr )( 8780 hrlyr x 1ton 12000lbl = 7.81E-02 N20

'* $$ QIIII_ ;**.,II"'~-** j "**,"EJ'~~,"'II"""'"** ;;p. , ,W 1fI;;;1i 4**atl~.IIjI{<ii:;;;** ,t, wus"!,, h"Iki\4ii,l4f ,<!" ",II1II) 4->4**l!,;lth~ Fii,¥h~**  s

# • • • 

# • Oakota-3 E&P Company, LLC
Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 

### Reciprocating Engine Emissions
ENGINE#2 56 'MAXHP

NOx: I 4.99E+OO ijJHP:AR] x ! .se-Ap] x 11 Ib I 453.6 grams I x 0.62 Iblhr x 8760**hr~** x 1 ton 12000lb' 2.70E+00 NOx TPY 2Q.;, I 3.1eE+00ij7Hp:A!f) x 56 HP x 11 Ib 1453.6srams

## I x 0.39 Iblhr x 8760**hr~** x 1ton 12000lb

## I = 1.71E+00 CO TPY I U8E..o1 glHP-HRI x 56 HP x 

## l' Ib I 453.6 Srams 

## I 3.31E..o2 Iblhr x 8760**h~** x 1ton 12000lb

## I 1.45E-01 802 TPY 

### " f.Mi 

### I 3.27E..o1 glHP-HRI x 56 HP , x 

## l' Ib 1453.6I1rams 

## I 4.04E..o2 Iblhr x 8760**hr~** x 1ton 12000tbi 1.77E-01 PM TPY ,9.80E+00 giHP-HR! x 56 HP x 11 Ib I 453.6I1rams x 1.21 Iblhr x 8760**hr~** x 1ton 12000lbl 5.30E+00 vee TPY HAP: I 2;:zoE-Ofg?HNi]l x 56 HP x 11 Ib I 453.6I1rams 0.03 Iblhr x 8760**hr~** x 1ton 12000tb

## I 1.19E-01 HAP TPY I 4.90E+02 giHPfiR] x 56 HP x 11 Ib I 453.6srams 6.05E+01 Iblhr x 8760**hr~** x 1ton 12000lb

## I 2.65E+02 C02 TPY CH4: 

### I 2.10E..o2 gIHP-HR! x 56 HP x 11 Ib 1453.6I1rams 2.59E..o3 Iblhr x 8760**hr~** x 1 ton 12000tb

## I 1.14E-02 CH4 TPY N20: ! 4.20E..o3 glHP-HRI x 56 HP x j1lb/453.6 grams 5.19E-04 Iblhr x 8760 hrlyr x 1 ton 12000lb

### I 2.27E-03 N20M:]

# • • 

# • 

# •

Olson-FBIR Pad Associated Wells: Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13·24HD 

# Dakota-3 E&P Company, LLC

Reciprocating Engine Emissions

TOTALS 3.04E+01 NOx TPY 5.03E+01 

### co TPY 1.45E'()1 502 TPV 1.77E'()1 PM TPY 7.t3E+OO VOC TPY 1.1tE'()1 HAP TPY 2.GSE+02 CO2 TPY 4.02E·01 CH4 TPY 8.03E'()2 N20TPY

# •
ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS

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

# •

•

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

# •

# •
van Hook Field 1000 BOPD wt% ****************************************************************************************** 

### * project Setup Information 

### * ****************************************************************************************** project File : y:\projects\williams Exploration & production WEP\WEP211324 Ft. Berthold IR well work\E&p Tanks\van Hook 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 Van Hook well Name pennington 16-1SH and Van Hook 16-14H Averages Permit Number oakota-3 E&P company, LLC Date 2010.09.24 ****************************************************************************************** 

### * Data Input 

### * 

# • ****************************************************************************************** Separator Pressure 52.00[psig]**Sep~rator** Temperature 90.00[F] Amblent Pressure 13.70[psia] Ambient Temperature SO.OO[F] C10+ SG 0.7970 C10+ MW 233.494 LOW Pressure oil
---------------------------------------------------------------------­ NO. component wt % . 1 H2S 0.0027 2 02 0.0000 3 C02 0.0038 4 N2 0.0008 5 C1 0.0261 6 c2 0.3417 7 c3 1.3723 8 i-c4 0.3662 9 n-c4 1.6928 10 i-CS 0.6858 11 n-C5 1.2496 12 c6 1.4712 13 C7 7.9550 14 C8 19.2940 15 C9 13.4810 16 C10+ 49.4241 17 Benzene 0.0470 18 Toluene 0.1281 19 E-Benzene 0.0586 20 xylenes 0.3912 21 n-c6 1.5420 22 224Trimethylp 0.4660 

# • sales oil
----------------------------------------------------------------------------­ production Rate 1000 [bbl/day] Days of Annual operation 365 [days/year] API Gravity 41.5 Reid vapor Pressure 6.20[psia] ****************************************************************************************** 

### * Calculation Results 

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

-- Emission Summary
---------------------------------------------------------------------­ Item uncontrolled uncontrolled [ton/yr] [1b/hr] page 1---------------------------------------------------------------- E&P TANK Total HAPs 6.040 1.379 Total HC 836.657 191.018 vocs, c2+ 823.270 187.961 VOCs, c3+ 649.305 148.243 Page 1 

# •

# • Van Hook F;eld 1000 SOPO**wt%~** uncontrolled Recovery Info. vapor 41.5700 [MSCFO] HC vapor 41.3600 [MSCFO] GOR 41.57 [sCF/bbl] Emission Composition
--------­ NO Component uncontrolled uncontrolled [ton/yr] [lb/hr] 1 H2s 1.343 0.307 2 02 0.000 0.000 3 co2 1.941 0.443 4 N2 0.412 0.094 5 C1 13.387 3.056 6 c2 173.965 39.718 7 c3 448.169 102.322 8 i-C4 34.294 7.830 9 n-C4 102.418 23.383 10 ;-c5 13.956 3.186 11 n-C5 18.394 4.200 12 c6 6.270 1.432 13 C7 10.476 2.392 

# • 14 c8 7.517 1.716 15 C9 1.774 0.405 16 c10+ 0.002 0.000 17 Benzene 0.156 0.036 18 Toluene 0.111 0.025 19 E-Benzene 0.016 0.004 20 xylene:s 0.090 0.021 21 n-C6 5.168 1.180 22 224Trimethylp 0.493 0.113 Total 840.352 191.861 Stream Data
--------------------------------------------------------------------------­ NO. Component MW LP oil Flash oil sale oil Flash Gas W&S Gas Total Emissions**~% ~% ~%** **~% ~%** **~%** 1 H2s 34.80 0.0027 0.0024 0.0001 0.1791 0.1609 0.1631 2 02 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 3 co2 44.01 0.0038 0.0026 0.0000 0.5796 0.1818 0.2307 4 N2 28.01 0.0008 0.0001 0.0000 0.3282 0.0099 0.0490 5 C1 16.04 0.0261 0.0112 0.0000 7.4009 0.7777 1.5911 6 c2 30.07 0.3417 0.2811 0.0024 30.3262 19.3302 20.6806 7 c3 44.10 1.3723 1.3000 0.5065 37.1767 55.5360 53.2811 8 i-c4 58.12 0.3662 0.3594 0.3044 3.7640 4.1203 4.0766 9 n-c4 58.12 1.6928 1.6719 1.5180 12.0581 12.1907 12.1744 10 i-C5 72.15 0.6858 0.6836 0.6696 1.7610 1.6447 1.6590 11 n-C5 72.15 1.2496 1.2474 1.2340 2.3296 2.1666 2.1866 12 C6 86.16 1.4712 1.4725 1.4830 0.8134 0.7577 0.7645 13 C7 100.20 7.9550 7.9683 8.0662 1.3546 1.2768 1.2865 14 C8 114.23 19.2940 19.3310 19.6004 0.9553 0.9145 0.9195 15 c9 128.28 13.4810 13.5078 13.7022 0.2134 0.2208 0.2201 16 C10+ 233.49 49.4241 49.5238 50.2483 0.0000 0.0000 0.0000 17 Benzene 78.11 0.0470 0.0471 0.0475 0.0197 0.0184 0.0186 18 Toluene 92.13 0.1281 0.1283 0.1300 0.0137 0.0131 0.0132 19 E-Benzene 106.17 0.0586 0.0587 0.0596 0.0020 0.0020 0.0018 

### It 20 xylenes 106.17 0.3912 0.3920 0.3976 0.0109 0.0106 0.0109 21 n-c6 86.18 1.5420 1.5438 1.5575 0.6517 0.6091 0.6143 22 224Trimethylp 114.24 0.4660 0.4668 0.4728 0.0617 0.0581 0.0587 MW 137.41 138.18 142.90 36.81 42.83 41.99 Stream Mole Ratio 1.0000 0.9924 0.9456 0.0076 0.0468 0.0544 Heating value [BTU/SCF] 2105.43 2442.60 2395.38 Gas Gravity [Gas/Air] 1.27 1.48 1.45 Bubble Pt. @ 100F [psia] 29.55 23.39 7.57 page 2---------------------------------------------------------------- E&P TANK RVP @ 100F [psia] 15.49 13.82 6.27 Spec. Gravity @ 100F 0.673 0.674 0.677 

# • Page 2

# • Oil 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 V2.0 Model, RVP Distillation Column As shown below, the E&P Tanks summary output has a linear relationship with the production rate of the oil with the given inputs listed below. Inputs: Low pressure oil from average of 2 representative Van Hook Field Dakota-3 Wells Separator: 52 pSig, 90 degF Flash Valve: 13.7 pSia, 50 degF Sales Oil: API Gravity 41.5, Reid Vapor Pressure 6.2 psia, 365 days/year 

# • Outputs: Oil Production Rates (bbl/day) (P) 0 50 100 300 1000 Emission (tons/yr) Total HC 0 41.83255 83.6651 250.9953 836.651 VOCs, C3+ 0 32.46485 64.9297 194.7891 649.297 Total HAPs 0 0.302 0.604 1.812 6.04 VOC (C3+) Emission Factor: 0.6493 tpy/BOPD HAP Emission Factor: 0.00604 tpy/BOPD 

### Tank Emissions 

### by Production Rate 700 600 500


## ... ......-Total HAPs CIS 400 _VOCs,C3+

## ~ 300 --Linear (Total HAPs) c 200 --Linear (VOCs, C3+) 

### S 100 

## o -100 bbl/day 

# •



# •

# •
ATTACHMENT D: REPRESENTATIVE LOW 

## PRESSURE OIL 

## ANALYTICAL DATA


# •

•

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

# •

# • Laboratory • Gas Measurement Emissions Testing • Sample Collection A2LA**Ac~lted** • /"iCtAl" Accredited • CPA Certlficd 29 Country Aerts Rd. HI...,rton. "'''' 82501 • TolIl'fte. C8fi6) 985-0866 • £·....11' Info(iH'.eclslon·t..b".eolll • Online, www.P'n:c:blon·t....... UIIII 

### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY Company
.................... ZENERGY Lab Number
................ CR-10330 Date Sampled
.............. 7-15-2010 Sample Identification
.................... VAN HOOK 16-14 H CRUDE Oil CR-S 7-23-2010

80F MONTRAIL yz PISTON 

# • Sample Location
.......... Sample Pressure
......... Type Sample
............... Test method
................ MONTANA. 28 PSIG SPOT GPA-2286 Components Mole%. Weight 0/0 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
..................... 0.009 0.002 0.000 0.000 0.010 0.003 0.003 0.001 0.184 0.021 1.152 0.241 3.568 1.096 0.778 0.315 3.694 1.496 1.242 0.624 2.270 1.141 2.276 1.367 10.418 7.274 24.125 19.203 16.003 14.302 30.668 50.576 0.090 0.049 0.183 0.117 0.047 0.035 0.455 0.337 2.304 1.384 0.521 0.415 100.000 100.000 Study Number•......... Date Tested
.............

Sample Temperature
.... County
...................... Sampling Method
........

Liq. Vol. % 0.002 0.000 0.003 0.001 0.051 0.501 1.600 0.414 1.896 0.739 1.339 1.523 7.823 20.117 14.658 46.892 0.041 0.100 0.030 0.288 1.542 0.441 100.000


# • 

# I

# •

ADDITIONAL BETX DATA Components Mole % Weight °/0 Liq. Vol. % 2-Methylpentane 1.293 0.777 0.866 3-Methylpentane 0.983 0.590 0.658 n-Hexane 2.304 1.384 1.542 2,2,4-Trimethylpentane 0.521 0.415 0.441 Benzene 0.090 0.049 0.041 Toluene 0.183 0.117 0.100 Ethylbenzene 0.047 0.035 0.030 m-Xylene 0.056 0.041 0.035 p-Xylene 0.291 0.216 0.184 o-Xylene 0.108 0.080 0.068 

# •

API GRAVITY AT 60/60 F. calculated
........................................................................ 59.7 SPECIFIC GRAVITY AT 60/60 F. calculated
............................................................ .. 0.7402 RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION
.............................. . 0.7983 AVERAGE MOLECULAR WEIGHT
.......................................................................... 143.505 AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION
.......................... 236.660 TRUE VAPOR PRESSURE AT 100 F. PSIA, calculated
.............................................. .. 28.847 AVERAGE BOILING POINT. F
................................................................................. 308.034 CUBIC FEET OF GAS I GALLON OF LIQUID, as Ideal Gas
......................................... . 18.973 BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated
................................................ . 122702.719 LBS I GALLON OF LIQUID, calculated
...................................................................... 6.171

:\( n ATlff
... AU (>\L( U.HI(**)!\:~.** PERFORillED L'SlN(' PHYSIC,]**C(l~S'L\NrS** FROM GPA .:2}45 09. THE 'fABLI·.5 Ul PHYSICAl**CO~ST:\"TS** FOR H)1)ROC>\RBONS .AND OTHI::R**C()~IPUl :;";D~·**  or INTEREST 

# .. 1'0THr. "IyftRAI C:\S INDl'STRY



# •

# • EXTENDED HYDROCARBON LIQUID STUDIES 

### CERTIF1CATE ()1- 

### ANALYSIS Company............... . ZENERGY Lab Number............. CR-I0330 Study Number.......... .. CR-5B DateSampled............ . 7-15-2010 DateTested.............. 7-22-2010 Sample Identification.............•.. VAN HOOK 16-14 H CRUDE OIL 

# I
Sample Location........ . MONTANA. 

# I 

# • Sample Pressure•......... N/A SampleTemperature.... N/A Flowrate................. .. N/A County•.....•.........•.... MONTRAIL 1-QUART TestMethod.............. VARIOUS Sample Container•...•.•. BOTfLE TEST PERFORMED API GRAVITYAT 60/60F (ASTM D-287), observed...................... SPECIFIC GRAVITYAT 60/60 F (ASTM D-1657), calculated.......... REIDVAPORPRESSURE (ASTM D-323), PSIGAT 100 F.............. TOTALSULFURCONTENT (ASTM D-5453), PPMW................. . TRUE VAPORPRESSURE (ASTM D-2889), PSIAAT 100 F ........... BASIC SEDIMENTAND WATERCONTENT, % BY VOLUME.... COPPERSTRIPCORROSION (ASTM D-130), 1HOURAT 100F........... FREEWATER, observed....................................................... .. 

# • RESULTS, 41.2 0.8193 4.6 PSIG 1,562.18 PPMW N/A N/A N/A N/A

NOTATION: ALL TESTING PROVIDEDABOVE WAS PERFORMED IN ACCORDA.:'ICE TO METHODOLOG\ OUTLINED BY THE AMERICAN SOCIETY FORTESTING AND MATERIALS (ASTM).



# •ubo".IOf) l'IusulCJtltnl f,mlniDru TbUng • 5Itmpk CoUecJlon

# PRE~ 

# • .A SIS Chromatogram VanHook 16-14 C:\GCso!ution\DRO\DRO Data\08-2010\08-01-2010\VanHook 16-14.gcd
- Channell



### o 100000 150000 200000 250000 Intensity

2.666/ ---------------4.069/
"-------------5.608/ Decane (CIO) ---------5,947/ "=".,---------------7,082/ 

# •

========:mm-:r------- 8.451/ """'::-:------------- 9,724 / ....:.:::.;:..;:..:...--------10,912/ -----------12.031/

-------13,087/

__hH.tfH---14.089/ 1-+----15.948/o-terphenyl



# •

:i' 

# • 3

# • Laboratory • Gas Measurement Emissions Testing • Sample Collection A2l..A Accredited • 1"t£l..Af' Accredited • EPA Certifled 29 Counlry ik
..... Rd. RI"",rton. lollY 82501 • Toll Fre",: (866)**98~..0866** • E-mail: Info@p.",clslon-Labs.c:om • Onlln",: wwv.Predslon·La.....c:om 

### EXTENDED HYDROCARBON (GLYCALC) UQUID STUDY Company
.................... ZENERGY lab Number
................ CR-10330 Study Number
.............. CR-4 Date Sampled
.............. 7-15-2010 Date Tested
................. 7-23-2010 

# • Sample Identification
.................... PENNINGTON 16-15 H CRUDE Oil Sample location
.......... MONTANA. Sample Pressure
......... 75 PSIG Sample Temperature
...... 100F Type Sample
............... SPOT County
........................ MONTRAll Test method
................ GPA-2286 Sampling Method
........ YZPISTON Components Mole % 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
..................... 0.012 0.000 0.013 0.004 0.270 2.018 5.113 0.980 4.432 1.409 2.562 2.488 11.732 22.998 13.316 28.387 0.078 0.204 0.107 0.573 2.688 0.616 100.000 Weight % 0.003 0.000 0.004 0.001 0.032 0.448 1.663 0.420 1.900 0.750 1.364 1.582 8.673 19.381 12.600 48.236 0.045 0.139 0.084 0.449 1.709 0.519 100.000 Liq. Vol. % 0.003 0.000 0.004 0.001 0.078 0.920 2.400 0.546 2.381 0.878 1.582 1.743 9.222 20.074 12.767 44.369 0.037 0.116 0.070 0.379 1.883 0.545 100.000 

# •

# •



# •

•



# • ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.398 0.889 0.979 3-Methylpentane 1.090 0.693 0.764 n-Hexane 2.688 1.709 1.883 2.2,4-Trimethylpentane 0.616 0.519 0.545 Benzene 0.078 0.045 0.037 Toluene 0.204 0.139 0.116 Ethylbenzene 0.107 0.084 0.070 m-Xylene 0.067 0.053 0.045 p-Xylene 0.386 0.302 0.255 o-Xylene 0.120 0.094 0.079

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

'(IT\TION \U C\LU, I**'\T\()"~** PFRl'llRMED l'SI:\l, PHYSIC>,l COt--ST-\l\:TS FRO?\ll;PA 214:,·(19, THF**L\BI.E~** OF PHYSIC\I U )l\:Sl \l\:T5 F(lR HYDRO( >,RB(l!\S \1\D OTHER U J;\jPUl'NDS (lll:\TEREST )'0 THL l\:.-\TlR-\1 (,,\5INDlSTR) 61.9 0.7318 0.7956 135.548 230.327

43.649 283.928

19.480 121815.044 6.102

# • EXTENDED HYDROCARBONLIQUID STUDIES 

### CERTIFICATE ()F :\\.lALYSIS Company............... . ZENERGY Lab Number............ . CR-10330 StudyNumber........... . CR-4B Date Sampled........... .. 7-15-2010 DateTested............ .. 7-22-2010 Sample Identification.............. .. PENNINGTON 16,·15 H CRUDE OIL 

# • SampleLocation........ . MONTANA. Sample Pressure........ .. N/A SampleTemperature... . N/A Flowrate.................. . N/A County.................... . MONTRAIL 1-QUART Test Method.............. VARIOUS Sample Container........ BOTI1..E TESTPERFORMED API GRAVITYAT60/60 F (ASTM D-287), observed.................... .. SPECIFIC GRAVITYAT60/60 F (ASTM D.1657), calculated......... . REIDVAPORPRESSURE (ASTM D.323), PSIGAT 100 F.............. TOTALSULFUR CONTENT (ASTM D-5453), PPMW................. . TRUEVAPORPRESSURE (ASTM D-2889), PSIAAT 100 F ......... .. BASIC SEDIMENTAND WATERCONTENT, % BY VOLUME.... COPPERSTRIPCORROSION (ASTM D-130), 1HOURAT

### too F........... FREEWATER, observed........................................................ . 

# • RESULTS 41.8 0.8165 7.8 PSIG 1,435.60 PPMW N/A N/A N/A N/A

NOTATION: ALL TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY OL'TLlNED BY THE AMERICA-'\! SOCIETY FORTESTING AND MATERIALS (ASTM),



# •Report(Report Editor)

Chromatogram Pennington 16-15H C:\GCsolution\DRO\DRO Oata\08-2010\08-01-201 O\Pennington 16-15H.gcd
- Channell 

### o 50000 100000 150000 200000 Labor.olory , Ga!o JiIIusuremt.nt 

# •**PRE~** £.mlnlona Tblmg • !leIl1pl«o CoUe<.lkin 

### .A :r 

### SIS



# •

•

• Intensity

3 :i' ==;;;;.J..:iJS",-

__ 3.637 1**""::::===~=====~;;;1------5.6091** DecaDe (CIO) ,... 5.9491 =-------------7.0831 =====8.6'33r-------8.4521**~----------** 9.7241

,;;,,;;,;--------10.9121 --------12.0301

-----­ 13.0871 ---nt"'nl'l"'t- 14.0901
15.948 Io-tetphenyl



# 30.01­ 2.6671

# •
ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS



# •

•

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

# •

# • • • 

# •

. LL4,r· methyl Hutlnll SpKIfIc AVI. coz Nltroa"n HilS Cl Q 0 1,(;4 n>C4 J.C5 n.(;S ca. 8enHn" ToIuen" E·8enr_ Xy"'n" "-Hexane pentane Va-Iu. Grmty MGktcufat welln.me iWt"l (Wt%) 

### 1M"""', iWt"l (WI'" iWt", iWt"l (Wt%) iWt", (Wt%, CSIWt%) C1(Wt%, iWt"l (Wt%, (Wt%) (Wt%) iWt", (Wt"} iWt", IBtu/scI) Calculated Weltht 44.010 28.013 34.081 16.043 30.069 44.096 58.122 58.122 72.149 72.149 86.1SO 101.21 114.23 78.112 92.140 106.170 106.160 86.ISO 114.230 Pennington 16-15 1.003 I 4.652 I 0.000 I 32.081 J 23.021 I 22.839J 2.571 I 7.695 1.238 I 1.722 1.nO 0.500 0.306 0.056 0.089 0.012 0.055 0.389 0 1511.141 0.927 26.848 MaryASmitl> 0.536 I 0.410 I 0.000 I 10.763 I 23.813 I 33.276 I 4.811 I 15.636 I 3.089 4.508 1.533 0.271 0.205 0.063 0.058 0.008 0.050 0.970 0 2117.258 1.2615 36.537 Averages: I 0.7695 I 2.531 I 0 I 21.422 I 23.417 I 28.0575 I 3.691 I 11.6655 I 2.1635 I 3.115 I 1.6515 I 0.3855 I 0.2555 I 0.0595 I 0.0735 I 0.01 I 0.0525 I 0.6795 I 0**L~** !.0942S1H.6925 Note: An calculations were preformed by PrecisionAn.lysis using physicalconstantsfrom GPA·2145-09.

# •

•

•



# • 29 Country Acres Rd, RIII.non, WY 82501 0 ..11...: _.Pr_I.lo..-l.8
....com 

# PRECISION/"' E-mall!.nfo4\lPr.c:I.lo..·U....com Toll Fl'e. Humb.... 1866, 98500866 

# -**.~s**
Client: Sample 10: Unique#: Sample Temperature: Sampled By: County: BISON ENGINEERING WILLIAMS PENNINGTON 16-15

57 DEG F TC DUNN
Components Mole % Carbon Dioxide
............. Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... Ethane
........................ Propane
....................... iso-Butane
...................**n-ButanE~** ...................... iso-Pentclne
.................. n-Pentane
.................... Cyclopentane
............... n-Hexane
..................... Cyclohexane................ Other Hexanes
............. Heptanes
..................... Methylcyclohexane........ 2,2,4-Trimethylpentane
... Benzene
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ Totals
........................ 0.612 0.000 4.459 53.689 20.s55 13.906

1.188 3.555 0.461 0.611 0.031 0.121 0.058 0.443 0.134 0.045 0.000 0.019 0.026 0.003 0.014 0.072 100.000 Weight % 1.003 0.000 4.652 32.081 23.021 22.839

2.571 7.695 1.238 1.641 0.081 0.389 0.181 1.423 0.500 0.166 0.000 0.056 0.089 0.012 0.055 0.306 100.000 AnalYSis Date: Date Sampled: Purpose: Sample Pressure: Type Sample:

Liq. Vol. % 0.490 0.000 2.300 42.686 25.781 17.967

1.823 5.256 0.790 1.038 0.043 0.234 0.092 0.855 0.290 0.086 0.000 0.025 0.041 0.005 0.025 0.173 100.000 10/11/2011 10/11/2011

40 PSI ONLINE

# •

ADDITIONAL BETX DATA Components Mole % Weight % Liq. Vol. % Cyclopentane 0.031 0.081 0.043 Cyclohexane 0.058 0.181 0.092 2-Methylpentane 0.279 0.895 0.538 3-Methylpentane 0.164 0.527 0.317 

# • n-Hexane 0.121 0.389 0.234 Methylcyclohexane 0.045 0.166 0.086 2.2.4-Trimethylpentane 0.000 0.000 0.000 Benzene 0.019 0.056 0.025 Toluene 0.026 0.089 0.041 Ethylbenzene 0.003 0.012 0.005 m-Xylene 0.002 0.009 0.004 p-Xylene 0.009 0.037 0.017 o-Xylene 0.002 0.009 0.004

SPECIFIC GRAVITY @60/60F, calculated.................................................. . TOTALGPM (Ethane Inclusive)................................................................. CALCULATED BTU / REAL CF @ 14.73 PSIA, drybasis.................................. CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis................................ .. AVERAGE MOLECULARWEIGHT........................................................... . MOLARMASS RATIO............................................................................. . RELATIVEDENSITY ( G x Z (Air) / Z ),calculated...................................... .. IDEALGROSS HEATINGVALUE, BTU / IDEAL CF @ 14.696 PSIA................. . COMPRESSIBIlJTYFACTOR (Z).............................................................. PROPANE GPM ..................................................................................... BUTANEGPM ...................................................................................... . GASOlJNE GPM (PENTANEAND HEAVIER) ......................................... .. :\OT**\TIO~** \LL l \Lll !-\TI( '''', I'ER]-( lR\ILn l SI'-:C, PHYS/( -\1 (O:\ST-\"rs fRO,\\ GPA 2145-\1'" THF T -\(JU5 

# • Of I'HYSH ,-\1 U l"-T -\"T:; r( lit HYDRUC "RHO"S ,\"D UTHER c().\II'(ll"m. 01 I"TFRFST TO THr \:\11 R-\1 (,\5 p;m STR\



# •

# •



# •

•



# • Z9 Country Acres Rd, RIverton, WY 825D1 Online:**_.Pr.cl.lon·~b** ••com 

# PRECISION:? E-mail.lnfoC!)Precl..**lon·~b** ...com Toll Free Numbe
.. (866)**985~866** 

# -**~SYS**
Client: Sample 10: Unique#: SampleTemperature: Sampled By: County: BISON ENGINEERING WILLIAMS MARY RSMITH

72 DEG F TC DUNN
Components Mole % Carbon Dioxide
............. Hydrogen Sulfide
........... Nitrogen
...................... Methane
...................... Ethane
........................ Propane
....................... iso-Butane
................... n-Butane
...................... iso-Pentane
.................. n-Pentane
.................... Cyclopentane
............... n-Hexane
..................... Cyclohexane
................ Other Hexanes
............. Heptanes
..................... Methylcycfohexane
........ 2,2,4-Trimethylpentane
... BenZenE!
...................... Toluene
....................... Ethylbenzene
............... Xylenes
....................... C8+ Heavies
................ Totals
........................ 0.445 '0.000 0.535 24.513 28.935 27.572

3.024 9.829 1.564 2.184 0.102 0.411 0.075 0.545 0.099 0.028 0.000 0.030 0.023 0.003 0.017 0.066 100.000 We!s:ht % 0.536 0.000 0.410 10.763 23.813 33.276

4.811 15.636 3.089 4.313 0.195 0.970 0.172 1.287 0.271 0.074 0.000 0.063 0.058 0.008 0.050 0.205 100.000 Analysis Date: Date Sampled: Purpose: Sample Pressure: Type Sample:

Liq. Vol. % 0.296 0.000 0.230 16.208 30.180 29.626

3.860 12.086

2.231 3.088 0.118 0.660 0.099 0.875 0.178 0.043 0.000 0.032 0.030 0.004 0.026 0.131 100.000 10/11/2011 10/11/2011

20 PSI ONLINE

# •

ADDITIONAL BETX DATA



# • Components Mole % Weight % Liq. Vol % Cyclopentane 0.102 0.195 0.118 Cyclohexane 0.075 0.172 0.099 2-Methylpentane 0.343 0.810 0.551 3-Methylpentane 0.202 0.477 0.324 n-Hexane 0.411 0.970 0.660 Methylcyclohexane 0.028 0.074 0.043 2,2,4-Trimethytpentane 0.000 0.000 0.000 Benzene 0.030 0.063 0.032 Toluene 0.023 0.058 0.030 Ethylbenzene 0.003 0.008 0.004 m-Xylene 0.003 0.008 0.004 p-Xylene 0.012 0.034 0.018 o-Xylene 0.003 0.008 0.004

SPECIFIC GRAVITY @ 60/60F,calculated.................................................. . TOTALGPM (Ethane Inclusive)................................................................. CALCULATED BTU / REALCF @ 14.73 PSIA, dry basis.................................. CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis.................................. AVERAGE MOLECULAR WEIGHT........................................................... . MOLAR MASS RATIO............................................................................. . RELATIVE DENSITY ( G x Z (Air) / Z ).calculated........................................ IDEALGROSS HEATINGVALUE, BTU / IDEALCF @ 14.696 PSIA................. . COMPRESSIBIUTYFACTOR (Z).............................................................. PROPANE GPM ................................................................................... .. BUTANEGPM ..................................................................................... .. GASOUNE GPM (PENTANEAND HEAVIER) ......................................... .. '>;( n**\Tl()~,** \L1 (,\Let 1**\n()~~** PF!{H lR\IED L SI'-:(, PH)',I( \1 «**l~~'j\"T~ !'RO~I**  CI',\,14',"': IHI I \BI E.'­ 

# • Or PHYSl( \J U**1~5T \~**  TO' H lR H\ DR()( \!{[I( ''''\'il) OTIII',R ( (t'\IP01'\l), Or**I~TL!{rYI** rOTHL "\Tl K\I C,,\, !"l)l 5TI\\



# • 1.2615 21.293 2111.258 2081.086

36.537 1.2615 1.2771 2086.694 

# I

0.98783 I r: 

## f 7.5766 4.0779 1.9202

# • ATTACHMENT F: ENGINE MANUFACTURER'S SPECS



# •

•

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

# •

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

# • RENTAL 

# C.i.TERPILLAR·

Arrangemant shown with optionaltl'lliler 

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

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

worldwide • Four-stroke-cycle diesel engine combines

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

characteristics ofdiesel engines • Permanent magnet excitation 

# • • Segregated ACIDC, 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 

# XQ230 

# SOUND ATTENUATED DUAL VOLTAGE 

### 50/60 Hz

ENVIRONMENTALLY FRIENDLY DESIGN • Sound attenuated for low noise operation • OSHA compliant safe design • 110% spill containment for coolant 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 stopcontacts SINGLE-SOURCE SUPPLIER • Complete systems designed at Caterpillar

ISO 9001:2000 certified facilities • Certified PrototypeTested with torsional

analysis WORLDWIDE PRODUCTSUPPORT • Worldwide parts availabilitythrough the

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

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

The best productsupport record inthe Industry. • Caterpillar dealerservice technicians are

trained to service every aspect ofyour electric power generation system.

LEHE5329-03 

# •

### FACTORY INSTALLED STANDARD AND OPTIONAL EQUIPMENT 

# • RENTAL 

# C.l.TERPILLAR­



# •

•



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

upon door opening) Individual bus bar connections Circuit breaker with 24 VDC shunttrip Remote start!stop contacts Shore powerconnections Enelollure Sound attenuated 12-gauge steel lockable doors Separate vented batterycompartment Single point lifting Exterior oil and waterdrains with interiorvalves Hidden exterior fuel drain Hand holds and steps Powder coated finish Fuel System Primary fuel filter/Water separator Ul142 dual wall fuel tank 1667 l (440 gal) Radiator-mounted fuel cooler Generator Brushless. permanent magnet Coastal corrosion protection Shock mounted VR6 voltage regulator Space heater UL approved Simultaneousthree-phase 480/277 and

240/139 voltage Mounting System Generator soft mounted to base Base contains Integral fuel tank Skiddable structural steel design 110% oil and coolant spill containment Starting System Electric starting motor Battery set with disconnect switch Jacket water heaterwith thermostat.

shut-offvalves opnONAlFEATURES Trailer Full frame support Independent tandem axle trailer frame

with tongue Electric actuated hydraulic brakes

with rechargeable battery backup breakaway system. Overcenter mechanical parking brake Full length fenders Non-skid surfece on steps Heavy duty safetychains and

grab hooks Reinforced 4540 kg (10,000 Ibl top

wind dropjack

LEHE5329-03 2

# • RENTAL

SPECIFICATIONS CAT SR4B GENERATOR Frame size •.........•.•.....•.••••••.•..•.••.....•••.•449 Type.•....•.•.....••........•.Permanant 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: %% noloedtofuilioed TIF ...........................................Less than 50 THO ••...•..•..•.••••......•••.•••••••••..•••Less than 6% 

# •

TECHNICAL DATA



# • ENGINE C9 ATAAC, 4-stroke-cycle watercooled diesel Bore
- mm lin) .•........•••••.••....•••••••••... 112 (4.41) Stroke
- mm (inl ................................ 149 (5.B7) Displacement - LIcu in) .......•••••••••...• " ••••.B.8 (637) Compression ratio•. "" .....•••.••••••..•••••••••.•. 16.1:1 Aspiration...••••.•..•.••.••Turbocharged AA charge cooled Engine control .••••.......••...••••••••••••••••ADEMltO A4 CAT CONTROL PANEL - EMCP 3.2 24VoltDC Control NEMA 1, 1P22 enclosure Lockable hinged door Enclosure mounted Single location customerconnector point 16 light alarm modulewith alarm hom Electricfuel level gauge Consultyour Caterpillar dealerfor available voltag...

X0230 Power Rilling

60Hz 50 Hz ekW kVA StllncI>Y lMIRef. PrIme 1M ..... 230 DM8502 210 DM851Z 276 DMaI504 EngIne andContainerInformation

Engine model Containerdimensions C9 seecharton3)8ge 6 Shipping Weight lOry)

Unit with trailer kg Ub) 6210 (13,6901 Unit withouttrailer Maximum Fuel CapacityWeight kg lib) 4980 (10,980)

Unitwithtrailer kg Ubi 7506 (16,5501 Unit withouttrailer kg Ub) 6278 (13,8401 Engine Lubricating 011 Capacity Engine CoolantCapacitywith Radiator FuelTankCapacity L(gal) L(gall L(gal) 40 (10.551 36 (9.6) 1516 (400) Fuel Consumption lJhr (gal/hr) 69.2 (18.31 6U(17.1) Fuel Consumption 176'110 PrIme) lJhr (gal/hr) 50.6 (13.41 RunningTIme @ 76% Prime SoundllMll hours 28

Standby dB(AI 74.72 No loed

### 0 7 m (23 ftl dB(AI 70.20 Prime dB(A) 73.49 Ambient Capability Deg C (Deg FI 43 1109.4)



# • LEHE5329-03 3 

## f I 

# i t i 

# I

# • RENTAL**C.ATERPILLAR~**



# •

•



# • RATING DEFINITIONS AND CONDITIONS Meets orExceeds International Specifications: • NEMA MG1-32, IEC 60034, CSA, 98/37/EEC, 72123/EEC,

UL 508, UL142,1503046/1,1508528, 89/336/EEC Standby
- Output available with varying loadfor the duration ofthe interruption ofthe normal source power. Standby powerIn accordance with 1508528. Fuel stop power in accordancewith IS0304611, A82789. DIN6271. and 855614. Prime
- Output available with varying load for an unlimited time. Prime powerin accordance with 1808528.10%overload powerill accordance with 1803046(1, AS2789, DIN6271, and 885514 available on requesl Ratings are based on SAE J 1349 standard conditions. These ratings also apply at 1503046/1, DIN6271, and B55514 standard conditions. Fuel rates are based onfuel oil of 35°API (@ 16° C 160· Fll gravityhaving an LHV of42 780 k.llkg 118,390 Btullb) whenused at290 C 1850 F) and weighing 838.9 gIIiter (7.001 IbJU.5. gal). Additional ratings may be available for specific customer requirements. ConsultyourCaterpillar representative for details.

lEHE5329-03 4

# • RENTAL 

# C.TERPILLARDISTRIBUTION PANEL



# •

r ."G.!!!!.-,
... -----.... 

# CATERPILLA

, 

# I :.: .;

- _J-_.j' :::}!y. • c'·' 11



# .. - , F.**~~** 

# • @f



# • Wiring Descriptions 1. 800 amp main breaker 240V with 24V shunttrip 2. 400 amp main 480V with 24V shunttrip 3. 50 amp 240V branch breaker 4. 20 amp 240V branch breaker 5. 20 amp 120V branch breaker 6. 15 amp 120V branch breaker 7. 50 amp240Vtwistlock receptacle 8. 20 amp 240V twistlock receptacle 9. 20 amp 120V twistlock receptacle (2x) 10. 20 amp 120V ground fault interrupter, (2x) 11. 15 amp 120V ground fault interrupter, duplex receptacle (2x) 12.30amp 120V battery charger/generator space heater receptacle 13.30amp 120VJWH receptacle 14. Remote start/stop contacts 15. 12.7 mm (W) ground stud 16. Dual voltage load connection bus board [6.35 mm 

### x 101.6 mm 

### x 101.6 mm (y.,. x 4" x 4·) bus bars]

LEHE5329-03 5 

# •

# • RENTAL 

# C.TERPILLARe

CONTAINER DIMENSIONS - TOP VIEW

212.8 (lo.74J-+--;--;

2540.0[100.00) 

### o 

# •**~--------------~·1{~r---------------~**



# •



# • CONTAINER DIMENSIONS - RIGHT SIDE VIEW

t--- .ZlB3.1 (93.84{

:l:2.25}
Overall Dimensions Package WithTrailer Length 4597.4mm 181 in 6248.3 mIT! 246 in Width 1498.6 mm 59 in 2640.0mm 100 in Height 2387.6mm 94 In 2882.8 inm 113.5 In

LEHE5329·03 6

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ATTACHMENT B: EMISSION INVENTORY



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

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# • ATTACHMENT G: EMISSION CONTROLDEVICE MANUFACTURER'S SPECS



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

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• CIMARRON ENERGY 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
. 

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# ! f**~** H&me oWe.: 1-(560) 336·5496 FAX 1-(S8C) US·CSSS P.O. Box 1406, Guym&n, Oklahoma 73942 Administrati
... Office; 1·{40S) 926·7373 FAX H40!} 928-1380 P.O. Soo 7221 to. Norma". OI<.I.homa 73070 

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POOR NUt» 48" DlA x 302 Sift'H6GHT, 88 ORlACES EMISSION CONTROL 0EVlCE

.. >98%WOC ORE, CERTlFlED USEPA 40 CFR 60, APPENDIX A, SClUR.CE fMfIIISIONS TEST METHODS REfERENC.E>. MEETS ALL EPA &; CDPHE REGULATIONS.

.. DESlROYS OILiCONOfNSATE PRODUCTION TANKVAPORS WI NOVISIBLE RAME
,. EXCEUHITOPACITYAND SMOKELESS OPERATION. • REI.1ABlfANDCUSTOMIZABLE IGNITlON. '" \/ERY lOW CAPITALAND OPERATING COST. '" fAS(TO OPERATEAND MAINTAIN.

.. WIllDESTROYUPTO 150MCFD @ 100Zf11 J 

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# • ATTACHMENT H: PROCESS FLOW DIAGRAM OF FACILITY



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

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------- TYPICALVAN HOOKAREA SEVEN WELLPAD FACILITYPLOTPLAN Dakota-3 E&P Company, LLC FBIR, North Dakota

NOT TO SCALE 

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# ATTACHMENT I: PRODUCTION DECLINE CURVE CALCULATIONS 

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

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## ATTACHMENT

# J: DIESEL TANKEPA 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 1of6

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

### TANKS 4.0.9d Emissions Report - Detail Format Tank Indentlflcation and Physical Characteristics
1000 gallon diesel tank Williston North Dakota Williams E&P, LLC Horizontal Tank 1 ,000 gallon diesel tank 10 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**fil~:/Ir:\Propram Fil~s\Tanks40QrI\sl1mmarvrlisnlav.hfm** 

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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

MixlUrelComponenl Monlh Daily liquid Surf. Temperalure (dog F) Avg. Min. Max. liquid Bulk Temp (degF) Vapor Pressure (psis) Avg. Min. Ma.. Vapor Mol. Weight. liquid Mass Fracl Vapor Mass Fract
. Mol. Welghl Ba.lslor Vapor Pressure Calculallons

.--..**-----~-------------------** ---- Disliilale fuel 011 no. 2 All 50.18 39.72 60.64 44.68 OJ)045 00031 0.0067 130.0000 188.00 ()pilon 1: VP50 •.0045 VP60 = .0065

9/2912011 file:llr:\ProlYram Files\Tanks409c1\sn.marvclisnlav.htm

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# • TANKS 4.0 Report 

### Page 30f6
TANKS 4.0.9d Emissions Report· Detail Format Detail Calculations (AP-42) 1000 gallon diesel tank - Horizontal Tank Williston, North Dakota

Annual Emission Calcaulallons Standing Losses (Ib):

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

Vapor Space Volume (cu It): Tank Diameter (II): Effechve Diameter (II): Vapor Space Outage (ft): Tank Shell Length (II): Vapor Densily

Vapor Densily (Ib/cu II): Vapor Molecular Weight (lbnb-mole): Vapor Pressure at Daily Average Liquid

Surface Temperature (psia): Daily Avg. Liquid Surface Temp. (deg. R): Daily Average Ambient Temp. (deg. F): Ideal Gas Constant R

(psia cull / (!b.mol-deg R)): liquid Bulk Temperalure (deg. R): Tank Pain! Solar Absorptance (Shell): Daily Total Solar Insulation

FaClor (Btu/sqll day): Vapor Space Expansion FaClor

Vapor Space Expansion Factor: Dally Vapor Temperature Range (deg. R): Daily Vapor Pressure Range (psla): Breather Vent Press. Sel1lng Range(psla): Vapor Pressure al Daily Average liquid

Sur1ace Temperature (psle): Vapor Pressure al Daily MInimum Liquid

Sur1ace Temperature (psla): Vapor Pressure at Dally Maximum Liquid

Sur1ace Temperature (psla): Daily Avg. Liquid Surface Temp. (deg R): Daily Min. Liquid Sur1ace Temp. (deg A): Daily Max. liquid Surface Temp. (deg A): Daily Ambient Temp. Range (deg. R): Venled Vapor Saturation Fador

Venled Vapor Saluration Fador: Vapor Pressure at Dally A_age Liquid:

Sur1ace Temperature (psle): Vapor Space Outage (It): Working Losses (Ib):

Vapor Molecular Weighl (lbnb.mole): vapor Pressure al Oally Average Liquid

Surface TemperalUre (psia): Annual Nel Throughput (gallyr.): 0.2654 66.5719 0.0001 0.0180 0.9995 86.5719 4.1600 1.2191 2.0800 10.0000 0.0001 130.0000

0.0045 509.8466 41.5958

10.731 504.3458

0.6800 1.276.2450 0.0160 41.8377 0.0036 0.0600 0.0045 0.0031 0.0061 509.8466 499.3812 520.3060 24.3583 0.9995 0.0045 2.0600 5.6720 130.0000

0.0045 2.244.312.0000

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# • Page 4 of6 TANKS 4.0 Report

Annual Turnovers: 2.244.3120 Tumover Faclor: 0.1800 Tank Diameter (fl): 4.1600 Working Loss Product Facto,: 1.0000 Tolat Losses (Ib): 5.9375

9/29/20\ \ filp·/lr·\PrrHl'r:lm Pilp<:\T:ln1c<:40QrI\<:nwml'lrvrli<:nll'lv htm

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### Page 5 of6


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

### I IComponents 

### II 

## II Working LosslI Losses(lbs} Breathing LosslI 

## I Total Emissionsl IDistiliate fuel oil no. 2 

## II 5.67\1 0.2711 5.941



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