I 

• 


APPLICATION FOR AN NSR 

PSD/TITLE V SYNTHETIC MINOR 

AIR QUALITY PERMIT 

PATRICIA CHARGING 2-158 

PAD OIL & GAS 

VCTI FACILITY 

Bison Engineering, Inc. 

1400 11th Avenue 

Helena, MT 

(406) 

www 

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

-
-
• 


DAKOTA-3 E&P COMPANY, LLC 

1\ subsidiary orWllliams 

1001 17111 Street, Suite 1200 

Denver. CO 80202 

303/527-3900 

DEC 29 2011 

8P-AR 

December 29, 20 II 

Ms. Kathleen Paser Duplicate submittal provided via e-mail to: 

Minor NSR Permitting Coordinator r8airpermitting@epa.gov 

• 

U.S. EPA, Region 8 


1595 Wynkoop Avenue, 8P-AR 


Denver, CO 80202-1129 

Re: Synthetic Minor Source Permit Application for the Patricia Charging 2-15H Pad 

Dear Ms. Paser: 

Dakota-3 E&P Company, LLC (Dakota-3) a subsidiary of WilJiams is submitting this Synthetic Minor 

Source Permit Application for the Patricia Charging 2-15H Pad. This application is being submitted in 

accordance with the requirements ofFederal Minor New Source Review Rule. 

Do not hesitate to contact me with any questions either by phone at 303-606·4056, or bye-mail at 

JoDell.Mizoue@Williams.com. 

Sincerely, 

Williams 


Dakota-3 E&P Company, LLC 


/dJ( 

JoDell Mizoue, P.E 


Staff' Environmental Special ist 


• 

Attachment 

cc: 	 File 

Joe Gillies Jr. Enviromnental Director, Environmental Division, 204 W. Main, 

New Town, NO 58763-9404 

Tex Hall, Chairman Three Affiliated Tribes, 404 Frontage Road, New Town, ND 58763-9404 

(letter Only) 

• 

• 


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 of the form. 

E(i) - Proposed New Facility 

Pollutant 

• 


PM 


PM)o 


PM 15 


SOl 


NOl 


CO 


VOC 


Pb 


Fluorides 


H2SO4 


H2S 


TRS 


RSC 


Potential Emissions 

(tpy) 

0.15 


0.15 


0.15 


0.05 


10.09 


18.99 


320.46 


Negligible 


Negligible 


Negligible 


Negligible 


Negligible 


Negligible 


Proposed Allowable 


Emissions 


(tpy) 


0.18 


0.18 


0.18 


0.05 


10.71 


22.33 


13.24 


Negligible 


Negligible 


Negligible 


Negligible 


Negligible 


Negligible 


PM - Particulate Matter 

PMlO - Particulate Matter less 

than 10 microns in size 

PM2.s - Particulate Matter less 

than 2.5 microns in size 

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic 

Compound 

Pb - Lead and lead compounds 

Fluorides - Gaseous and 

particulates 

H2S04 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur 

Compounds 

Emissions calculations must include fugitive emissions ifthe source is one the following listed 

sources, pursuant to CAA Section 302(j): 

(a) Coal cleaning plants (with thermal dryers); (r) Sintering plants; 

(b) Kraft pulp mills; (s) Secondary metal production plants; 

(c) Portland cement plants; (1) Chemical process plants 

(d) Primary zinc smelters; (u) Fossil-fuel boilers (or combination thereof) totaling 

(e) Iron and steel mills; more than 250 million British thermal units per hour 

(f) Primary aluminum ore reduction plants; heat input; 

• 

(g) Primary copper smelters; (v) Petroleum storage and transfer units with a total 

(h) Municipal incinerators capable of charging more than storage capacity exceeding 300,000 barrels; 

250 tons ofrefuse per day; (w) Taconite ore processing plants; 

(i) Hydrofluoric, sulfuric, or nitric acid plants; (x) Glass fiber processing plants; 

(j) Petroleum refineries; (y) Charcoal production plants; 

(k) Lime plants; (z) Fossil fuel-fired steam electric plants ofmore that 

(I) Phosphate rock processing plants; 250 million British thermal units per hour heat input, 

(m) Coke oven batteries; and 

(n) Sulfur recovery plants; (aa) Any other stationary source category which, as of 

(0) Carbon black plants (furnace process); August 7, 1980, is being regulated under section I II or 

(p) Primary lead smelters; 112 ofthe Act. 

(q) Fuel conversion plants; 

• 

• 

E(ii) - Proposed New Construction at an Existing Facility or Modification of an Existing Facility 

This section ofthe application is not applicable. The application is for a new facility only. 

Pollutant Current 

Actual 

Emissions 

(tpy) 

Current 

Allowable 

Emissions 

(tpy) 

Post-Change 

Potential 

Emissions 

(tpy) 

Post-Change 

Allowable 

Emissions 

(tpy) 

PM N/A N/A N/A N/A 

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

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

SO~ N/A N/A N/A N/A 

NO~ N/A N/A N/A N/A 

CO N/A N/A N/A N/A 

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

Pb N/A N/A N/A N/A 

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

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

H 2SO4 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 

PMlO - Particulate Matter less than 10 microns in size 

PM2.5 - Particulate Matter less than 2.5 microns in size 

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic Compound 

Pb - Lead and lead compounds 

NH3 - Ammonia 

Fluorides - Gaseous and particulates 

H2S04 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur Compounds 

• 
• 


Instructions 

Use of This Form 

• 	 Proposed new construction or modifications should first be evaluated to detennine ifthe change is 

major under the major NSR program using the procedures at 40 CFR 52.21 (i.e., baseline actual to 

projected actual applicability test). Ifthe proposed construction does not qualify as a major under 

that test, then it may be subject to the requirements ofthe minor NSR rule at 40 CFR 49.151. 

Helpful Definitions from the Federal Minor NSR Rule (40 CFR 49) - This is not a comprehensive list. 

• 	 40 CFR 49.152(d) - Modification means any physical or operational change at a source that would 

cause an increase in the allowable emissions ofthe affected emissions units for any regulated NSR 

pollutant or that would cause the emission of any regulated NSR pollutant not previously emitted. 

The following exemptions apply: 

(1) A physical or operational change does not include routine maintenance, repair, or replacement. 

(2) An increase in the hours ofoperation or in the production rate is not considered an operational 

change unless such increase is prohibited under any federally-enforceable permit condition or 

other pennit condition that is enforceable as a practical matter. 

(3) A change in ownership at a source is not considered a modification. 

• 	 40 CFR 49. 152(d) - Allowable emissions means "allowable emissions" as defined in 

§52.21(b)(16), except that the allowable emissions for any emissions unit are calculated 

considering any emission limitations that are enforceable as a practical matter on the emissions 

unit's potential to emit. 

• 	 52.21(b)(16) - Allowable emissions means the emissions rate ofa stationary source calculated 

using the maximum rated capacity ofthe source (unless the source is subject to federally 

enforceable limits which restrict the operating rate, or hours ofoperation, or both) and the most 

stringent ofthe fo Bowing: 

• 


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


(ii) The applicable State Implementation Plan emissions limitation, including those with a future 

compliance date; or 

(iii) The emissions rate specified as a federally enforceable permit condition, including those with 

a future compliance date. 

• 	

Page 7 of 15 
• 

A. General Facility Information 

I. Company Name & Operator Name (if different): Provide the complete company and operator names. For 

corporations, include divisions or subsidiary name, if any. 

2. Facility Name: Provide the facility name. Please note that a facility is a site, place, location, etc ... that may 

contain one or more air pollution emitting units. 

3. Type ofOperation: Indicate the generally accepted name for the operation (Le., asphalt plant, gas station, dry 

cleaner, sand & gravel mining, oil and gas wellsite, tank battery, etc.). 

4. Portable Source: Does the facility operate in more than one location? Some examples of portable sources 

include asphalt batch plants and concrete batch plants. 

5. Temporary Source: A temporary source, in general, would have emissions that are expected last less than 2 

years. Do you expect to cease operations within the next 2 years? • 

6. NAICS Code: North American Industry Classification System. The NAICS Code for your facility can be 

found at the following link ~ North American Industry Classification System 

(http://www.census.gov/epcd/naics/nsic2ndx.htm#Sl). 

7. SIC Code: Standard Industrial Classification Code. Although the new North American Industry 

Classification System (NAICS) has replaced the SIC codes, much ofthe Clean Air Act permitting processes 

continue to use these codes. The SIC Code for your facility can be found at the following link ~ Standard 

Industrial Classification Code (http://www.osha.gov/plslimis/sic manual.htrnl). 

8. Physical Address: Provide the actual address of where the facility is operating, not the mailing address. 

Include the State and the ZIP Code. 

9. Reservation: Provide the name ofthe Indian reservation within which the facility is operating. 

10. County: Provide the County within which the facility is operating. 

Ila & lIb. Latitude & Longitude: These are GPS (global positioning system) coordinates. This information 

can be provided in decimal format or degree-minute-second format. 

12a 12d. Section-Township-Range: Please provide these coordinates in 114 SectioniSection/Township/Range. 

(e.g., SW Y4, NE Y4 IS36ITIONIR2IE). 

• 

Page 8 of 15 

• 
• 


B. 	Current Permit Information 

Provide a list ofall permits that have been issued to your facility. This should include any Federal 

Minor New Source Review (MNSR), Prevention ofSignificant Deterioration (PSD) or NonAttainment New Source Review (NA NSR) permits, in addition to the most recent Part 71 permit. The 

permit number must be included with each permit identified. 

C. 	Contact Information 

Please provide the information requested in full. 

1. Company Contact: List the full name (last, middle initial, first) of the owners of the facility or the company 

contact. 

• 
 2. Operator Contact: Provide the name ofthe operator of the facility if it is different from the company contact. 


3. Facility Contact: The facility contact must be the local contact authorized to receive requests for data and 

information. 

4. Compliance Contact: The compliance contact must be the local contact responsible for the facility's 

compliance with this rule. If this is the same as the Facility Contact please note this on the form. 

D. 	Attachments 

This section lists the information needed to complete the requested approval. This 

information should be accompanied by the supporting information listed on the form and 

described below. The information should be presented in enough detail to document how the 

facility is currently operating and/or how it is proposed to operate. 

,f 	FORM SYNMIN 

If synthetic minor limits are being requested, we recommend that the information from checklist tiled Form 

SYNMIN be included with this application. 

,f 	Narrative description of the proposed production processes. 

• 

1. The narrative description should follow the flow of the process flow diagram to be submitted 

with this application. This needs to be as comprehensive as possible to help in understanding the 

proposed facility and how it will be operated. For example: 

What are the raw materials? 


What are the properties of the raw materials? 


Does the production process include heating, drying, the application of chemicals, etc? 


How will the raw materials be affected by this process? 


What are the out puts from each step of the process (Le., crushed ore, dry gas, water, etc ... )? 


Etc .... 


2. 	 The proposed operating schedule presented in terms of hours per day, days per week, 

and weeks per year. 

3. 	 A list ofthe type and quantity of fuels and/or raw materials used. Each fuel and raw 

material should be described in enough detail to indicate its basic chemical 

components. 

• 	

Page 9 of 15 
• 

,f 	A process flow chart identifying all proposed processing, combustion, handling, storage, and emission 

control equipment (include the unit identification # or code). This flow chart should illustrate the detailed 

narrative description requested above . 

./ 	List and describe all proposed units, emission units and air pollution-generating activities. At a 

minimum, provide the following: 

1. 	 The hourly, daily and annual maximum operating rates for each operating unit, 


production process, and activity. 


2. 	 The hourly, daily and annual maximum firing rates for each fuel and combustion 


equipment. 


3. 	 The capacity for storage units and the hourly, daily and annual maximum throughput 


ofmaterial in the storage units. 


4. 	 Material and product handling equipment and the hourly, daily and annual maximum 


throughput of material and product. 


S. 	 Tank designs, tank storage capacities, hourly, daily and annual maximum throughput • 

of material and product. 

,f 	Type and quantity of fuels, including sulfur content of fuels, proposed to be used on a daily, annual and 

maximum hourly basis. 

,f 	Type and quantity of raw materials used or final product produced proposed to be used on a daily, annual 

and maximum hourly basis. 

,f 	Proposed operating schedule, including number of hours per day, number ofdays per week and number of 

weeks per year. 

,f 	A list and description of all proposed emission controls, control efficiencies, emission limits, and 

monitoring for each emission unit and air pollution generating activity. 

1. 	 Include manufacturer specifications and guarantees for each control device. 

., 

Page 10 of15 

• 
• 


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, PMJO, PM2.5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile 

organic compound (VOC), lead (Pb) and lead compounds, ammonia (NH3), fluorides (gaseous and 

particulate), sulfuric acid mist (H2S04), hydrogen sulfide (H2S), total reduced sulfur (TRS) and 

reduced sulfur compounds, including all calculations for the estimates. 

I. 	 These estimates are to be made for each emission unit, emission generating activity, in addition 

to total emissions. 

• 

2. The information should include all ofthe supporting calculations, assumptions and 

references. Emission estimates must address all emission units and pollutants proposed 

and/or affected by the limitation and be presented in short term (e.g. pounds per hour) 

as well as annual (tons per year) units. 

3. 	 Any emission estimates submitted to the Regional Administrator must be verifiable 

using currently accepted engineering criteria. The following procedures are generally 

acceptable for estimating emissions from air pollution sources: 

• 	 Source-specific emission tests; 

• 	 Mass balance calculations; 

• 	 Published, verifiable emission factors that are applicable to the source. (Le. manufacturer 

specifications) 

• 	 Other engineering calculations; or 

• 	 Other procedures to estimate emissions specifically approved by the Regional 

Administrator. 

4. 	 Guidance for estimating emissions can be found at 


http://www.epa.gov/ttnlchief/efuac/index.html. 


Current Actual Emissions: Current actual emissions for a pollutant is expressed in tpy and 

generally is calculated by multiplying the actual hourly emissions rate in pounds per hour 

(lbs/hr) times actual hours operated (which is the number ofhours in a year) and dividing 

by 2,000 (which is the number ofpounds in a ton) . 

• 1. For an existing air pollution source (permitted and unpermitted) that operated prior to the 

application submittal, the current actual emissions are the actual rate of emissions for the 

preceding calendar year and must be calculated using the actual operating hours, production 

rates, in-place control equipment, and types of materials processed, stored, or combusted 

during the preceding calendar year. The emission estimates must be based upon actual test data 

or, in the absence of such 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 allowed hourly emissions rate in pounds per hour (Ibs/hr) 

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

number ofpounds in a ton). 

1. 	 "Allowed" means the source is restricted by permit conditions that limit its emissions and are 

enforceable as a practical matter (i.e., allowable emissions). The allowable emissions for any 

• 	

Page II of 15 
• 

emissions unit are calculated considering any emissions limitations that are enforceable as a 


practical matter on the unit's PTE. 


2. 	 For an existing permitted air pollution source that operated prior to the application submittal, the 

current allowable emissions are the allowable rate of emissions for the preceding calendar year and must 

be calculated using the permitted operating hours, production rates, in-place control equipment, and 

types of materials processed, stored, or combusted during the preceding calendar year. 

3. 	 For an existing air pollution source that does not have an established allowable 

emissions level prior to the modification must report the pre-change uncontrolled 

emissions. 

Post-Change Potential Emissions (Potential uncontrolled emissions from proposed project): This is 

the maximum capacity of a source to emit a pollutant under its physical and operational design. 

This is expressed in tpy and generally is calculated by multiplying the maximum hourly emissions 

rate in pounds per hour (lbs/hr) times 8,760 hours (which is the number ofhours in a year) and 

dividing by 2,000 (which is the number ofpounds in a ton). 

•

Post-Change Allowable Emissions: A source's allowable emissions for a pollutant is expressed in 

tpy and generally is calculated by multiplying the allowed hourly emissions rate in pounds per hour 

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

is the number ofpounds in a ton). 

L 	 Unless the source is restricted by permit conditions or other requirements that are enforceable 

as a practical matter, the post-change allowable emissions would be equivalent to post-change 

uncontrolled emissions. For the post-change allowable emissions a lower level of allowable 

emissions may be proposed. 

2. 	 For physical or operational changes at minor sources and for minor physical or operational 

changes at major sources, the total increase in allowable emissions resulting from your 

proposed change would be the sum of following: 

• 	 For each new emissions unit that is to be added, the emissions increase would be the 


potential to emit ofeach unit. 


• 	 For each emissions unit with an allowable emissions limit that is to be changed or 


replaced, the emissions increase would be the allowable emissions ofthe emissions unit 


after the change or replacement minus the allowable emissions prior to the change or 


replacement. However, this may not be a negative value. Ifthe allowable emissions of an 
 •

emissions unit would be reduced as a result of the change or replacement, use zero in the 

calculation. 

• 	 For each unpermitted emissions unit (Le., a unit without any emissions limitations before 


the change) that is to be changed or replaced, the emissions increase would be the 


allowable emissions ofthe unit after the change or replacement minus the potential to emit 


prior to the change or replacement. However, this may not be a negative value. Ifthe 


allowable emissions of an emissions unit would be reduced as a result ofthe change or 


replacement, use zero in the calculation. 


Page 12 of 15 

• 
• 


./ Modeling Analysis 

Do I need to do a modeling analysis? 

The Federal Minor New Source Review Regulations at 40 CFR 49.1S9(d) requires that a modeling 

analysis (AQIA) ofproposed emissions be performed if there is reason to be concerned that new 

construction would cause or contribute to a National Ambient Air Quality Standard (NAAQS) or 

Prevention ofSignificant Deterioration (PSD) increment violation. 

In addition, ifthe AQIA reveals that the new construction could cause or contribute to a NAAQS or 

PSD increment violation; such impacts must be reduced before a pre-construction permit can be 

issued. 

To facilitate the protection ofthe NAAQS and PSD Increment, EPA Region 8 requests that those 

• proposed activities that meet the following criteria perform an AQIA: 

1. 	 The proposed activity has air emissions that EPA Region 8 determines have the potential to 

cause adverse air quality effects for which an air quality impact analysis is necessary for an 

accurate assessment ofthe environmental impact ofthe activities proposed. 

2. 	 Modeling ofproposed emissions is usually warranted, even though the proposed activity does 

not meet the modeling requirements, above, if it is reasonable to believe the new activity may 

cause or contribute to a violation of applicable ambient air quality standards or increments in 

circumstances such as: 

(a) A substantial portion ofthe new or modified emissions have poor dispersion characteristics 

(e.g., rain caps, horizontal stacks, fugitive releases, or building downwash) in close 

proximity to ambient air at the site boundary; 

(b) The new or modified emissions are located in complex terrain (e.g., terrain above stack 

height in close proximity to the source); or 

(c) The new or modified emissions are located in areas with existing air quality concerns. 

• 

(d) If you have questions about whether modeling may be necessary based on the 4th criteria 

above, please contact EPA Region 8's Modeling Lead: 

Gail Tonnesen 

Region 8 Modeling Lead 

Tonnesen.gail(w,epa.gov 

303-312- 6113 

• 	

Page J3 of 15 
• 

What Kind ofAir Quality Modeling Analysis Is Needed? 

I. 	 EPA Region 8 considers a stepped or phased approach to modeling to be appropriate, as 

follows: 

Step I: Qualitative Air Quality Assessment 

Step 2: Screening Modeling Analysis 

Step 3: Preliminary Modeling Analysis (refmed modeling) 

Step 4: Full Impact Modeling Analysis (refmed modeling) 

Step 5: PSD Increment and NAAQS Analysis 

Step 6: Additional Impact Analysis 

2. 	 Step I: Qualitative Air Quality Assessment 

Narrative description ofthe current air quality conditions and the expected impact the permitted 

•

source would have on that air quality. Some suggested factors to consider in the qualitative 

discussion could include meteorology, terrain, distance to ambient air, expected emissions, etc. 

Ifa convincing case cannot be made qualitatively that no impacts to air quality would be 

expected, a screening analysis should next be performed. 

3. 	 Step 2: Screening Analysis 

For proposed new or modified sources that meet the modeling requirement criteria identified 

above, protection of air quality from proposed emissions may be shown by using a simple 

screening technique (e.g., SCREEN3 or AERSCREEN). Screening models are available for 

download at the EPA SCRAM website: 

http://www.epa.gov/ttn/scramldispersionscreening.htm. A pre-approved modeling protocol is 

not necessary prior to conducting a Screening Analysis. 

4. 	 Ifthe proposed new or modified emission increases do not increase ambient concentrations ofa 

pollutant by more than the significant impact levels, as compared to the SILs identified below, no 

further modeling is necessary. 

S'19m'fileant I mjJact Leve I s 

, 

• 

I 

Pollutant A veraging Period Class II Area SIL 

(uwm3) 

Class I Area SIL 

(uWm3) 

S02 

1 hr 3 ppb or 7.8 ug/m> (interim) ---... 

3hr 25 1.0 

24 hr 5 0.2 

Annual 1 0.08 

PM2.5 24 hr 0.07 1.2 

Annual 0.06 0.3 

I PM10 

24 hr 5 0.2 

Annual 1 0.08 

N02 

I hr 4 ppb or 7.5 ug!m' (interim) ---­

Annual I 0.08 

CO 1 hr 

8 hr 

2,000ppb 

500ppb 

Note: The Class I area SILs are provided as guidance and have not been formalized by EPA. 

Page 14 of) 5 

• 
• 


5. 	 Sources that cannot demonstrate protection of air quality using a screening technique should 

continue to the modeling requirements in Step 3 through Step 6. Modeling in Steps 3 through 

6 should be performed based an approved protocol. 

6. 	 Applicants are encouraged to contact the EPA Region 8 Modeling Lead prior to conducting any 

refined modeling analysis (Step 3 through Step 6) to obtain an approved protocol. 

What Should I Include In My Application If Modeling Is Necessary? 

1. 	 Approved Modeling Protocol 

In order to expedite the permitting process, it is recommended that you include a protocol that 

has already been approved. An application will not be deemed complete until the protocol has 

been approved. 

• 2. Modeling Results 

In 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 U.S. Fish and Wildlife Service 

andlor the NOAA Fisheries Service, to ensure that actions we authorize are not likely to jeopardize the 

continued existence ofany listed species or result in the destruction or adverse modification of 

designated critical habitat ofsuch species. 

To expedite the approval ofyour proposed construction, we encourage you to identify any listed 

species that you may be readily aware ofthat could be affected by your proposal. The following 

website has been provided to assist you: 

http://www.fws.gov/endangeredl 

Simply enter the State and County in which you propose to construct to obtain a general listing . 

• ./ NHPA 

The National Historic Preservation Act requires us, in consultation with State andlor Tribal Historic 

Preservation Officers to ensure that actions we authorize are not likely to affect cultural resources. 

To expedite the approval of your proposed construction, we encourage you to identify any cultural 

resources that you may be readily aware ofthat could be affected by your proposal. The following 

website has been provided to assist you: 

1:!t1p;/Inrlm. focus. nps. gov /patreghome. do?searchtype=nat regho me 

Simply enter the State and County in which you propose to construct to obtain a general listing. 

• 	

Page 15 ofl5 
• 

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 

Region 8 Air Program 

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

Checklist - Synthetic Minor Limit Request 

(Form SYNMIN) 

Use ofthis information request form is voluntary and not yet approved by the Office of Management and Budget. The 

following is a check list ofthe type of information that Region 8 will use to process information on your proposed project While 

submittal of this 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 of application forms for this program is currently under 

Office of Management and Budget review and these information request forms will be replaced/updated after that review is 

completed. 

Please submit information to fo))owing two entities: 

Company Name 

Dakota-3 E&P Company, LLC 

Facility Name 

Patricia Charging 2-15H Pad 

Company Contact or Owner Name 

JoDell Mizoue 

Title 

Staff Environmental 

Specialist 

Mailing Address 

1001 I i h Street, Suite 1200 Denver, CO 80202 

Email Address 

JoDell.Mizoue@Williams.com 

Telephone Number 

(303) 606-4056 

Facsimile Number 

(303) 692-8285 

The Tribal Environmental Contact for the specific reservation: • 

Ifyou need assistance in identifying the appropriate Tribal 

Environmental Contact and address, please contact the EPA 

Region 8 Tribal Air Coordinator: 

Alexis North, EPA Region 8 Tribal Air Coordinator 

303-312-7005 

north.alexis@epa.gov 

• 

For each criteria air pollutant, hazardous air pollutant and for all emission units and air pollutantgenerating activities to be covered by a limitation, include the following: 

../ 	 Item 1 - The proposed limitation and a description of its effect on current actual, allowable and the potential to 

emit. 

../ 	 Item 2 - The proposed testing, monitoring, recordkeeping, and reporting requirements to be used to demonstrate 

and assure compliance with the proposed limitation . 

../ 	 Item 3 - A description of estimated efficiency of air pollution control equipment under present or anticipated 

operating conditions, including documentation of the manufacturer specifications and guarantees . 

../ 	 Item 4 - Estimates of the Post-Change Allowable Emissions that would result from compliance with the proposed 

limitation, including all calculations for the estimates . 

../ 	 Item 5 Estimates of the potential emissions of Greenhouse Gas (GHG) pollutants before and after proposed 

emission controls. 

Federal Minor NSR Permit Coordinator 

U.S. EPA, Region 8 

1595 Wynkoop Avenue, 8P-AR 

Denver, CO 80202-1129 

A. GENERAL INFORMATION 


B. ATTACHMENTS 

• 


Instructions 

Use this form to provide general and summary information about the synthetic minor NSR 

source (facility or plant) on Tribal lands and to indicate the emissions limitations requested. 

Submit this form once, in addition to FORM NEW, for each synthetic minor NSR source on 

Tribal lands. 

1. Who Can Request Federally-Enforceable Limitations Under the Tribal NSR Authority? 

The Tribal NSR Rule applies only to sources located within the exterior boundaries ofan Indian 

reservation in the United States ofAmerica or other lands as specified in 40 CFR part 49, collectively 

referred to as "Indian country". So, to use the authority in the Tribal NSR Rule to create federally­

• enforceable limitations, a facility must be located within Indian country. Land ownership status (for 

example, whether the land is owned by a Tribal member or whether the land is owned in fee or in trust) 

does not affect how the rule applies. 

2. Who Might Want to Request Federally-Enforceable Limitations? 

The primary reason for requesting federally-enforceable limitations is to avoid an otherwise applicable 

federal Clean Air Act program, rule or requirement. Many federal Clean Air Act programs use a 

source's "potential to emit" (PTE) air pollution to determine which rules or requirements apply. A 

facility's PTE is based on the maximum annual operational (production, throughput, etc) rate ofthe 

facility taking into consideration the capacity and configuration ofthe equipment and operations. 

Emission or operational limits can also be taken into consideration as maximums ifthey are federally 

enforceable. So, using a synthetic minor NSR permit to establish federally enforceable limitations can 

lower a facility's PTE and possibly allow the facility to avoid certain federal Clean Air Act 

requirements. 

Three examples offederal Clean Air Act programs that use PTE to determine whether they apply are 

• 

(I) the Prevention ofSignificant Deterioration (PSD) construction permitting program, (2) the Title V 

operating permit program, and (3) the Maximum Achievable Control Technology (MACT) program. 

For example, existing sources that are considered "major" for Title V (meaning they have the potential 

to emit air pollution at levels defmed in that rule as "major") must apply for a Title V operating permit. 

If a source accepts a federally-enforceable limitation through a synthetic minor NSR permit that 

reduces their PTE to below the "major" threshold, and the source does not meet any ofthe other 

requirements that would trigger applicability to the part 71 program, then the source no longer needs a 

Title V operating permit. When planning for the construction ofa new source or expansion ofan 

existing source, a source can also accept limitations on PTE (using a synthetic minor NSR permit) that 

allow the source to avoid PSD. Limitations on PTE can 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 must be attached to the application form for each requested 

limitation. The requested limitation(s) must be described for each affected emissions unit (or pollutantgenerating activity) and pollutant and must be accompanied by the supporting information listed on the 

form and described below. Note that applicability of many federal Clean Air Act 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 by that given rule or regulation must 

be addressed by this section ofthe application form. 

Item 1 - The requested limitation and its effect on actual emissions or potential to emit must be 

presented in enough detail to document how the limitation will limit the source's actual or potential 

emissions as a legal and practical matter and, if applicable, will allow the source to avoid an otherwise 

applicable requirement. The information presented 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 Item 4 below to explain how the limitation affects emissions before and after the limitation is in 

effect. 

Item 2 - For each requested limitation, the application must include proposed testing, monitoring, 

recordkeeping and reporting that will be used to demonstrate and assure compliance with the 

limitation. Testing approaches should incorporate and reference appropriate EPA reference methods 

where applicable. Monitoring should describe the emission, control or process parameters that will be 

relied on and should address frequency, methods, and quality assurance. 

Item 3 - The application must include a description and estimated efficiency ofair pollution control 

equipment under present or anticipated operating conditions. For control equipment that is not 

proposed to be modified to meet the requested limit, simply note that fact; however, for equipment that 

is proposed to be modified (e.g. improved efficiency) or newly installed to meet the proposed limit, 

address both current and future descriptions and efficiencies. Include manufacturer specifications and 

guarantees for each control device. 

Items 4 - Any emission estimates submitted to the Regional Administrator must be 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. (Le., manufacturer 


specifications). 


(iv) Other engineering calculations; or 

(v) Other procedures to estimate emissions specifically approved by the Regional Administrator. 

Post-Change Allowable Emissions: A source's allowable emissions for a pollutant is expressed in tpy 

and generally is calculated by multiplying the allowed hourly emissions rate in pounds per hour 

(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 potential to emit GHG emissions ofat least 100,000 

tpy C02e and 100 or 250 tpy on a mass basis, modifications at existing PSD facilities that increase 

GHG emissions by at least 75,000 tpy C02e and minor sources that increase GHG emissions by at least 

100,000 tpy C02e and 100 or 250 tpyon a mass basis are subject to PSD permitting requirements, even 

ifthey do not significantly increase emissions of any other pollutant. As such, any requested limits to 

avoid PSD must take into account greenhouse gases. 

Therefore, please include in your permit application estimates ofthe potential emissions ofthe 

following pollutants before and after proposed emission controls. More information about GHG 

permitting and how to calculate C02 equivalents (C02e), the mass emissions of each individual GHG 

• 

• 

Page 3 of4 • 
• 


adjusted for its Global Warming Potential (GWP) can be found at: 

http:// epa.gov/nsr/ ghgdocs/ ghgpermittingguidance. pdf 

1. Carbon dioxide (C02) 

2. Methane (CH4) and its C02e 

3. Nitrous oxide (N20) and its C02e 

4. Hydrofluorocarbons (HFCs) and its C02e 

5. Perfluorocarbons (PFCs) and its C02e 

6. Sulfur hexafluoride (SF6) and its C02e 

• 

• 

• Page 4 of4 
• 

PATRICIA CHARGING 2-15H PAD ATTACHMENTS: 

Attachment A: Application Report 

Attachment B: Emission Inventory 

Attachment C: Flashing Emissions Calculations 

Attachment D: Representative Low Pressure Oil Analytical Data 

Attachment E: Representative Gas Analysis 

Attachment F: Engine Manufacturer's Specs 

Attachment G: Emission Control Device Manufacturer's Specs 

Attachment H: Process Flow Diagram of Facility 

Attachment I: Production Decline Curve Calculations 

Attachment J: Diesel Tank EPA TANKS 4.09d Emission Summary 

• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 
ATTACHMENT A: APPLICATION REPORT 


• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 
• 


C. CONTACT INFORMATION 


• 


• 


Company Contact: JoDell Mizoue ITitle: 

. Staff Environmental 

i Specialist 

Mailing Address: 1001 171n Street, Suite 1200 Denver, CO 80202 

Email Address: JoDell.Mizoue@WiIliams.com 

Telephone Number: (303) 606-4056 Facsimile Number: (303) 692-8285 

Operator Contact (if different from company contact): Same as above Title 

Mailing Address 

Email Address 

Telephone Number Facsimile Number 

Facility Contact: Same as above Title 

Mailing Address 

Email Address 

Telephone Number Facsimile Number 

Compliance Contact: Same as above Title 

i 

Mailing Address 

Email Address 

Telephone Number Facsimile Number 

• 

• 

D. ATTACHMENTS 


Include all ofthe following information (see the attached instructions) 


../ 	 FORM SYNMIN - New Source Review Synthetic Minor Limit Request Form, if synthetic minor limits are 

being requested . 

../ 	 Narrative description of the proposed production processes. This description should follow the flow of 

the process flow diagram to be submitted with this application . 

../ 	 Process flow chart identifying all proposed processing, combustion, handling, storage, and emission control 

equipment . 

../ 	 A list and descriptions ofall proposed emission units and air pollution-generating activities . 

../ 	 Type and quantity of fuels, including sulfur content of fuels, proposed to be used on a daily, annual and 

maximum hourly basis. • 

../ 	 Type and quantity of raw materials used or final product produced proposed to be used on a daily, annual and 

maximum hourly basis . 

../ 	 Proposed operating schedule, including number of hours per day, number ofdays per week and number of 

weeks per year. 

../ 	 A list and description of all proposed emission controls, control efficiencies, emission limits, and monitoring 

for each emission unit and air pollution generating activity . 

../ 	 Criteria Pollutant Emissions - Estimates of Current Actual Emissions, Current Allowable Emissions, PostChange Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants: 

particulate matter, PMJO, PM2,5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile 

organic compound (VOC), lead (Pb) and lead compounds, fluorides (gaseous and particulate), sulfuric acid 

mist (H2S04), hydrogen sulfide (HzS), total reduced sulfur (TRS) and reduced sulfur compounds, including all 

calculations for the estimates . 

../ 	 These estimates are to be made for each emission unit, emission generating activity, and the project/facility in 

total. 

../ 	 Modeling - Air Quality Impact Analysis (AQIA) 

../ 	 ESA (Endangered Species Act) 

../ 	 NHPAJNational Historic Preservation Act) 

•

• 
• 


• 


APPLICATION FOR AN NSR 


PSD/TITLE V SYNTHETIC MINOR 


AIR QUALITY PERMIT 


PATRICIA CHARGING 2-15H 


PAD OIL & GAS 


PRODUCTION FACILITY 


Prepared for: 

Dakota-3 E&P Company, LLC 

1001 17th Street, Suite 1200 

Denver, CO 80202 

Prepared by: 

• 


Bison Engineering, Inc. 


1400 11th Avenue 


Helena, MT 59601 


(406) 442-5768 


www.bison-eng.com 

December 29, 2011 
• 

TABLE OF CONTENTS 

1.0 INTRODUCTION .................................................................................................. 1 


1.1 Summary ................................................................................................... 1 


1.2 Site Location .............................................................................................. 1 


1.3 Site Description .......................................................................................... 1 


2.0 NARRATIVE DESCRiPTION................................................................................ 2 


3.0 POTENTIAL TO EMIT ESTIMATE ....................................................................... 4 


3.1 Production Storage Tank VOC Emissions ................................................. 7 


3.2 Produced Casing Head Gas Emissions ..................................................... 7 


• 
 3.3 Reciprocating Intemal Combustion or Compression Ignition Engines ....... 8 


3.4 Natural Gas External Combustion Unit Emissions ..................................... 8 


3.5 Truck Loading Emissions ........................................................................... 8 


3.6 Fugitive Emissions: Dust and Equipment Leaks ....................................... 8 


4.0 EMISSIONS AND OPERATIONAL LIMITS REQUESTS ..................................... 9 


4.1 Production Storage Tank Emissions .......................................................... 9 


4.2 Reciprocating Intemal Combustion or Compression Ignition Engines ....... 9 


5.0 ALLOWABLE EMiSSiONS ................................................................................. 10 


5.1 Storage Tank Emissions .......................................................................... 10 


5.2 Produced Casing Head Gas Emissions ................................................... 10 


5.3 Rice Engine Emissions ............................................................................ 10 


5.4 Natural Gas External Combustion Unit Emissions ................................... 10 


5.5 Truck Loading Emissions ......................................................................... 11 


5.6 Fugitive Emissions: Dust and Equipment Leaks ..................................... 11 


5.7 Diesel Storage Tank Emissions ............................................................... 11 


6.0 PROPOSED MONITORING AND RECORDKEEPING ...................................... 12 


6.1 Production Storage Tanks ....................................................................... 12 


6.2 Production Storage Tank Emissions Control Device ............................... 13 


6.3

• 6.4 

Produced Casing Head Gas Emergency Utility Flare 

Rice Engines ..............................................................

.............................. 

.............................. 

15 


16 


6.5 Natural Gas-Fired External Combustion Units ......................................... 16 


6.6 Truck Loading .......................................................................................... 17 


6.7 Fugitive Emissions: Dust and Equipment Leaks ..................................... 17 


6.8 General Recordkeeping Requirements .................................................... 19 


7.0 QUALITATIVE AIR QUALITY ASSESSMENT .................................................... 20 


8.0 ENDANGERED SPECIES ACT .......................................................................... 21 


9.0 NATIONAL HISTORIC PRESERVATION ACT .................................................. 22 


Patricia Charging 2-15H Pad 12/29111 pg. ii 


NSR Synthetic Minor Permit Application 


Project #: WEP211324 

• 

FIGURES 


Figure 1: Example of Maximum PTE from a Seven Well Pad ................................... 5 


Figure 2: Example of Actual Production from a Seven Well Pad .............................. 6 


ATTACHMENTS 

Attachment A: 


Attachment B: 


Attachment C: 


Attachment D: 


Attachment E: 


Attachment F: 


Attachment G: 


Attachment H: 


Attachment I: 


Attachment J: 


Application Report 

Emission Inventory Spreadsheets 

E&P Tank V2 Emission Summary Output 

Representative Low Pressure Oil Analytical Data 

Representative 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 

• 

Patricia Charging 2-15H Pad 12/29111 pg. iii 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


1.0 INTRODUCTION 


1.1. Summary 

Dakota-3 E&P Company, LLC (Dakota-3) is submitting this application for a Prevention 

of Significant Deterioration (PSD) and/or Part 71 Title V (Title V) synthetic minor permit 

to the Environmental Protection Agency (Agency) in accordance with the Federal Minor 

New Source Review (NSR) Rule (40 CFR 49) adopted pursuant to the Federal Clean 

Air Act. 

• 

Dakota-3 is proposing to construct and operate the Patricia Charging 2-15H Oil and Gas 

(O&G) production facility on the FBIR. Included in this application for a synthetic minor 

permit are allowable emissions speCified by requested federally enforceable permit 

conditions that 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 of the application. 

1.2. Site Location 

The Patricia Charging 2-15H Pad is proposed to be located in the northwest % of the 

northeast % Section 15, Township 149 North. Range 93 West, Dunn County, on the 

FBIR in North Dakota. 

1.3. Site Description 

At the proposed Patricia Charging 2-15H Pad there will be two oil and gas wells that are 

proposed to produce to the facility. The facility will be situated on an approximately ten 

acre site, with an elevation of approximately 2,000 feet (mean sea level), in Dunn 

County, North Dakota. The surrounding area is mainly used for agriculture and livestock 

grazing. The proposed pad's associated well names are: 

1. Patricia Charging 2-15HC 

2. Patricia Charging 2-15HD 

• 

The names of the wells may be subject to change due to landowner requirements, 

drilling location changes, timing of well leases, etc. The Agency will be notified if the 

names change. 

Patricia Charging 2-15H Pad pg. 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 

• 

2.0 NARRATIVE DESCRIPTION 


This section of the application provides a detailed description of the operations at the 

Patricia Charging 2-15H Pad. For purposes of estimating emissions from this facility, the 

combined first twelve-month potential production from the two proposed wells at this 

facility was used. These production rates can be found in Attachment B, Emission 

Inventory. 

The production rates used in this application are grossly overestimated when compared 

to the actual predicted production rates in the first and subsequent years. The wells that 

will be producing to this facility do not begin producing at the same time. In reality, there 

will be up to six or more years' difference in when the initial production from wells begin 

to when the final wells are constructed and begin to produce. It is not physically possible 

for all of the wells to be simultaneously drilled and begin initial production. However, to 

•

allow for reasonable flexibility and to be conservative, this application has considered a 

maximum potential production case from the pad. Due to ever-changing drilling 

schedules, completion schedules, economics, etc., the wells will begin actual production 

at different times. 

The entire pad facility will consist of the following primary production equipment and 

capabilities. 

2 - Heater Treater/Separators 2 - Line-Heaters (0.75 MMBtu/hr max) 

8 - Oil Production Tanks 1 - Gasoline Recycling Pump 

2 - Produced Water Tanks 2 - Electric Lifting Units 

2 - Oil and Gas Producing Wells 1 - Truck Loading Rack 

1 - Manufactured Produced Gas Flare 2 - Diesel Engines 

1 - Manufactured Enclosed Tank Vapor Combustor 

The oil/gas/water emulsion being produced from the wells is transported up each 

wellbore using an electric lifting unit. The emulsion from the wells producing to this site 

is transported in a closed system to individual two-phased separators and then to the 

three-phase separators (heater treaters). The initial two-phase separator reduces the 

pressure of the oil/gas/water emulsion to allow the gas to separate from the oil and 

water. The heater treaters then reduce the pressure closer to ambient pressure and 

heat the leftover emulsion using a flame-arrested line-heater. The combination of higher • 

temperatures and low pressures allow for additional separation of the gas/oil/water 

phases from each other because of differences in densities. The line-heater is fueled by 

onsite produced casing head gas that is routed to the heater's combustion chamber. 

Propane may also be used as an alternative fuel if necessary. Following the heater 

treater the oil and water are routed to their separate storage tanks. 

The produced casing head gas is transferred from the two-phase separators to the 

sales gas pipeline. An onsile utility flare serves as an emergency backup in the event 

that the gas cannot be placed into the sales line. The oil and water production tank's 

working, standing, breathing, and flashing vapors are routed to an enclosed combustion 

• 

Patricia Charging 2·15H Pad 12/29111 pg.2 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


device. The stored oil is typically transported for sale via the Lease Automated Custody 

Transfer (LACT) unit, with the truck loadout serving as an emergency backup if there 

was a malfunction with the oil pipeline. Produced water is stored in the onsite water 

storage tank until it is transported offsite using the water pipeline. 

At the facility, there is a small gasoline fueled pump located near the production storage 

tanks. This pump is commonly known as a "transfer" or "recycle." The pump is used to 

periodically recycle the liquids (oil/water) in the bottom of the production tanks back into 

the heater treater for further separation. Otherwise. the facility is completely electrified; 

however. the electricity lines have not yet been installed at the facility. Onsite diesel 

genset engines will provide electricity until transmission lines are installed. 

• 

A process flow diagram and plot plan of the site is shown in Attachment H. 

• 

Patricia Charging 2-15H Pad 12/29/11 pg. 3 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

3.0 POTENTIAL TO 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 of the 

well will greatly decline over the initial twelve months of production. Assuming that each 

well's production would be equivalent to the initial production will grossly overestimate 

production and is not realistic for how an oil and gas well operates. The decline curve 

calculated for this facility was developed using existing well data from wells previously 

drilled and producing in the same region. The confidential decline curve estimations are 

included in Attachment I of the application. 

As noted in Section 2.0 above, determination of potential emissions from the proposed 

Patricia Charging 2-15H Pad has been approached in a very conservative fashion. The 

combined production rate for the pad assumes all of the wells start production 

simultaneously (represented in example Figure 1). With this assumption, the initial 30­

day production from each well is summed to estimate a potential total production rate 

from the pad. Operating practice is that the wells will be drilled over time, often months 

or even years apart. Further, after each well is drilled and brought into production, the 

initial production rate generally decreases greatly before the next well is drilled. 

Therefore, this potential to emit (PTE) estimate is meant only to define an outer 

envelope of emissions for permitting applicability purposes. Furthermore, the allowable 

emissions estimates presented in Section 4 are also very conservative compared to 

anticipated actual emissions that could be emitted at the facility during any given 12­

month rolling average. An example demonstrating the predicted production of a 

theoretical multiple well pad over an extended period of time is presented in Figure 2. 

This example does not represent predicted production from the well pad being permitted 

in this application; however, it does serve to demonstrate typical operations for this type 

of facility. 

• 

• 

Patricia Charging 2-15H Pad 12/29/11 pg.4 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• • • 

• • 

••••••••••••••• 

• 

Figure 1: Example of Maximum PTE from a Seven Well Pad 

Exam of Maximum PTE from a Seven Well Pad 

6,000 

• 	 ~II seven wells begin 


production
 5,000 simultaneously 

R'OOO ~ • ~ 

., •

J,ooo -+­

• 	 Total Production from Seven 

Wells on Pad f 	 +.­ :1,000 •

.

...... 

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

o 

o 	 10 20 30 40 

Month 

Patricia Charging 2-15H Pad 12129/11 pg.5 

NSR Synthetic Minor Pennit Application 

Project #: WEP211324 
• • • • 

Figure 2: Example of Actual Production from a Seven Well Pad 

Example of Actual Production From a Seven-Well Well Pad 


3,500 


II 6th and 7th wells begin 


production 


3,000 

2,500 

Q 

Go 

i 

GI 2,000 

! 

S 

5th well begins production 

2nd well begins production 

1st well begins production 

""-Total Production from Seven Wells on Pad 

~ -12-Month Rolling Average Oil Production 

ii 1,500 c -12-Month Rolling Average Oil Production Limit 

~ 

1,000 

500 

o 

o 5 10 15 20 25 30 35 40 

Month 

Patricia Charging 2-15H Pad 12129111 pg.6 

NSR Synthetic Minor Permit Application 

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 Tank VOC 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% of the vapor components, 

such as VOCs, HAPs, GHGs, etc. 

• All applicable uncontrolled emissions from the storage tanks calculations, low pressure 

analytical data, and E&P TANKS program inputs and outputs are provided in the 

attachments. 

3.2 Produced Casing Head Gas Emissions 

At the two-phase separator, +90% of all of the initial casing head gas is separated and 

sent to the gas sales pipeline. After the initial separation occurs, the leftover emulsified 

oil/gas/water is transferred to the three-phase heater treater. The heater treater then 

separates the residual gas from the oil and water. Due to the reduced pressure of the 

heater treater, the sales pipeline pressure is too high to overcome; therefore, the 

residual gas is routed to the onsite utility flare. Furthermore, if the gas sales pipeline 

Patricia Charging 2-15H Pad 12/29/11 pg. 7 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

pressure increases to the point at which the produced casing head gas from the twophased separator cannot be sold or the gas pipeline has a malfunction, the flare serves 

as an emergency backup. 

3.3 Reciprocating Internal Combustion or Compression Ignition Engines 

Diesel engines connected to generators provide the facility with electricity. The potential 

emissions from the engines are estimated by assuming the engine is operating 8,760 

hours per year and applying the federally required 40 CFR 63 Subpart JJJJ or 40 CFR 

60 Subparts 1111 and ZZZZ emission limits as applicable. 

3.4 Natural Gas 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 Btu/hr. The emissions 

are based on AP-42 factors and assume the heater is running 8,760 hours per year. 

3.5 Truck Loading Emissions 

The facility is hooked to the oil pipeline via the LACT unit; therefore, no emissions are 

associated with truck loading. The only time truck loading would occur is under 

emergency or malfunction situations. 

3.6 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 and production begins in order 

to track to the twelve-month rolling average actual emissions. The fugitive leak 

emissions primarily consist of leaks from connectors, open-ended lines, valves, pumps, 

etc. These emissions will be estimated using EPA's average emissions factors for total 

hydrocarbon emissions from O&G production operations. The fugitive dust emissions 

will be estimated using AP-42 factors to capture the emissions associated with vehicle 

traffic at the location. 

• 

• 

• 

Patricia Charging 2-15H Pad 12/29/11 pg.8 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 

4.0 EMISSIONS AND OPERATIONAL LIMITS REQUESTS 

Oatoka-3 is requesting emissions and operational limits at the Patricia Charging 2-15H 

Pad in order to obtain a synthetic minor status with regard to the NSR permitting 

programs. The federally enforceable permit conditions will allow Oakota-3 to operate the 

facility while emitting less than the PSOrritle V major source thresholds of 250/100 tons 

per year of a regulated criteria pollutant, 10 tons per year of an individual HAP, and 25 

tons per year of all emitted HAPs. 

4.1 Production Storage Tank Emissions 

• The majority of emissions associated with the facility occur from the working, breathing. 

standing, and flashing vapors from the production storage tanks. Therefore, Oakota-3 

will control the storage tank VOC emissions by installing an enclosed smokeless 

combustion device that has been independently tested and certified to exceed the 

requirements of 40 CFR 60.18 at 98% destruction efficiency (ORE). Although this 

control device is certified to meet 99% ORE, Oakota-3 will assume the minimum 

required 98% ORE for purposes of calculating the controlled tank vapor emissions. This 

control device will allow Oakota-3 to apply a 98% control efficiency to the uncontrolled 

PTE. On this basis, the requested emission limit from the storage tanks is: 6.27 tons per 

year of VOCs. 

4.2 Reciprocating Internal Combustion or Compression Ignition Engines 

Oakota-3 will be required to limit the emissions from any reciprocating internal 

combustion or compression ignition engine being operated at the facility due to the 

federally enforceable requirements of 40 CFR 63 Subpart JJJJ or 40 CFR 60 Subparts 

1111 and ZU2, as applicable. 

• 

Patricia Charging 2·15H pg. 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 

• 

5.0 ALLOWABLE EMISSIONS 


The allowable emissions are the new estimated controlled potential to emit based on 

the federally enforceable controls and limits requested in Section 4. The allowable 

emissions are also presented in the Application for New Construction (Form NEW), 

Table E(i) Proposed New Facility. 

5.1 Storage Tank Emissions 

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 

and N20 emissions 

are reduced 

are 

by 

created 

the smokeless 

by the combustion 

combustion 

process. 

device, 

These 

CO, NO

emissions 

x• PM, PM10. 

estimates 

PM2.5 •

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, if the gas sales pipeline 

pressure increases to the point at which the produced casing head gas from the twophased separator cannot be sold or the gas pipeline has a malfunction, the flare serves 

as an emergency backup. No limits have been requested for the produced casing head 

gas emissions at the facility; therefore, the emissions estimate is equal to the potential 

to emit. 

5.3 RICE Engine Emissions 

No limits have been requested for the RICE at the facility. Dakota-3 is required to meet 

the federally enforceable emission standards depending on the size (hp) and date of 

manufacture; therefore, the emissions estimate is equal to the uncontrolled potential to 

emit. • 

5.4 Natural Gas External Combustion Unit Emissions 

No limits have been requested for the natural gas external combustion units (0.5-0.75 

MMBtu/hr heater treater line-heaters) at the facility; therefore, the emissions estimate is 

equal to the uncontrolled potential to emit. 

Patricia Charging 2-15H Pad 12129111 pg.10 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


• 


• 


5.5 Truck Loading Emissions 

The facility is connected to the oil pipeline via the LACT unit; therefore, no emissions 

are associated with truck loading. The only time truck loading would occur is under 

emergency or malfunction situations if the oil pipeline went down; therefore, no limits 

are requested. 

5.6 Fugitive Emissions: Dust and Equipment Leaks 

Fugitive emissions from eqUipment leaks and dust are not required to be estimated for 

purposes of potential to emit within the NSR permitting program. However, the fugitive 

emissions will be estimated after a final permit is issued in order to track the twelvemonth rolling average actual emissions. The fugitive leak emissions primarily consist of 

leaks from connectors, open-ended lines, valves, pumps, etc. These emissions will be 

estimated using EPA's average emissions factors for total hydrocarbon emissions from 

O&G production operations. The fugitive dust emissions will be estimated using AP-42 

factors to capture the emissions associated with vehicle traffic on the location. 

5.7 Diesel Storage Tank Emissions 

There will be an onsite storage tank at this facility to store diesel fuel that will be utilized 

in the diesel gensets. This tank will be either a horizontal or vertical 1,000 gallon tank. 

Emissions for this tank were estimated using EPA TANKS 4.09d and determined to be 

less than 0.01 tpy. Because of the low level of emissions from this equipment, it has 

been determined to have insignificant emissions. The EPA TANKS 4.09d emissions 

summary output is in Attachment J. I 

I 

Patricia Charging 2·15H pg. 

NSR Synthetic Minor Pennit Application 

Project #: WEP211324 

.. 

• 

6.0 PROPOSED MONITORING AND RECORDKEEPING 


As per the Application for Synthetic Minor Limit Request (Form SYNMIN), Page 1 (8), 

ATTACHMENTS, Item, 2. Datoka-3 is required to propose testing, monitoring. 

recordkeeping, and reporting requirements that will be used to demonstrate and assure 

compliance with the proposed allowable emissions. 

6.1 Production Storage Tanks 

The production storage tanks will have their flashing and standing/working/breathing 

vapors routed by a closed-vent system to equipment designed to capture the VOC and 

total HAP emissions generated at the facility for sale or other beneficial purposes, or an 

emissions control device that achieves a minimum of 98% destruction efficiency. 

Dakota-3 will follow the tank manufacturer's recommended maintenance schedule and 

•

procedures to ensure optimum performance. Furthermore, Dakota-3 will employ the 

following methods to ensure the tank vapors are efficiently being routed to the 

requested proposed device( s): 

a. 	 Thief hatch covers will be weighted and properly seated; 

b. 	 Pressure relief valves (PRV) will be set to release at a pressure that will ensure 


flashing, and standing/working/breathing losses are routed through a closed-vent 


system to equipment designed to capture the VOC and total HAP vapors. The 


vapors will be routed to equipment designed for sale or other beneficial purpose, 


or an emissions control device; and 


c. 	 Periodic measurements of the peak pressure and vacuum values in the vapor 


recovery and control systems will be conducted to ensure that the pressure and 


vacuum relief set-points are not being exceeded (e.g., due to fouling or increased 


activity levels) resulting in venting and possible damage to equipment. 


Monitoring Requirements: 

Dakota-3 will estimate the emissions from the production storage tanks by performing 

one of the 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 of flashing emissions by sampling and lab analysis; 

d. 	 Process simulator such as PROMAX, HYSIM, HSYS using site-specific sampling 


and lab analysis to calculate flashing emissions in conjunction with EPA TANKS 


4.0.9d to calculate standing/working/breathing losses; 


e. 	 API E&P TANKS Software V2.0 using representative sampling and lab analysis 


to calculate standinglworking/breathing losses and flashing emissions; or 


f. 	 Other methods approved by EPA. 

Patricia Charging 2-15H Pad 12/29/11 pg.12 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


Recordkeeping Requirements: 

In order to demonstrate compliance with the 12-month rolling emission limits for the oil 

production tanks, Dakota-3 will track facility oil production rates for each month, 

beginning with the first full calendar month after operations commenced. The monthly 

totals will be summed to create a production rate for the prior twelve month rolling 

operating period. As demonstrated in Attachment e of this application, the total voe, 

total HAP, and any single HAP emissions in tons per year are directly proportional to the 

production rate of oil at the facility. Based upon this relationship, compliance with the 

requested limits in this application will have been maintained if the production rate 

during any twelve month rolling period is less than the production rate used to establish 

the emission limits. 

• Dakota-3 will keep records of all input parameters and calculations, including the input 

and output reports for the models, used to determine the monthly emissions. 

6.2 Production Storage Tank Emissions 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 voe (or voe and HAP) emissions in the vapors vented to 

the device by at least 98%. 

Dakota-3 will follow, for each enclosed combustion device and utility flare, the 

manufacturer's written operating instructions, procedures and maintenance schedule to 

ensure good air pollution control practices for minimizing emissions. 

All vent lines, connections, fittings, valves, relief valves, or any other appurtenance 

employed to contain and collect vapors and transport them to the enclosed combustor, 

or utility flare will be maintained and operated during any time the facility is operating. 

Each enclosed combustion device will be: 

• 	 a. Designed to have sufficient capacity to achieve at least a 98% destruction 

efficiency for hydrocarbon volumetric flow and BTU content routed to the device; 

b. 	 Operated with a liquid knock-out system to condense any condensable vapors; 

c. 	 Equipped with a thermocouple to detect the presence of a pilot flame with a 

minimum accuracy of ±2 percent of the temperature being monitored expressed 

in °e, or ±2.S °e; 

d. 	 Equipped with a recording device, such as a chart recorder or similar device, to 

document the presence of a flame; 

e. 	 Equipped with an electronically controlled ignition system with a malfunction 

alarm and remote notification system if the pilot flame fails; 

f. 	 Maintained in a leak-free condition; and 

g. 	 Operated in a smokeless mode. 

Patricia Charging 2-15H Pad 12/29/11 pg. 13 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

Monitoring Requirements: 

Dakota-3 will identify, via an independent engineering analysis or a manufacturer or 

vendor guarantee, each control device's operating parameters within which they will 

meet the 98.0% reduction requirement. Dakota-3 will monitor the control device 

operations to confirm proper operation as follows: 

a. 	 Monitor the pilot flame using a thermocouple and a chart recorder that indicates 


the continuous ignition of the pilot flame; 


b. 	 An inspection of the chart recorder to ensure proper operation will be done 


whenever an operator is on site; at a minimum, quarterly; 


c. 	 A visual inspection of the pilot flame to ensure proper operation will be done 


whenever an operator is on site; at a minimum, quarterly; 


d. 	 Measure one other parameter determined during the independent engineering •

analysis or provide a manufacturer or vendor guarantee; and 

e. 	 Visually confirm that no smoke is present during operation of any enclosed 


combustor or utility flare whenever an operator is on site; at a minimum, 


quarterly. 


Recordkeeping Requirements: 

a. 	 Records will be kept of the site~specific design input parameters provided for the 


independent engineering analysis or provided to the manufacturer or vendor and 


used to properly size the enclosed combustors and utility flares to assure the 


98% reduction requirements. 


b. 	 Records will be kept of all required monitoring of the control device operations. 

c. 	 Records will be kept of any instances in which any control device was bypassed 


or down in each calendar month, the reason for each incident. its duration, and 


the corrective actions taken or the preventative measures adopted to avoid such 


bypasses or downtimes. 


d. 	 Records will be kept of the any exceedance of the operating parameters 


specified in the manufacturer or vendor guarantee or engineering analysis and 


selected for the required monitoring. The records will include the enclosed 


combustor's total operating time during the calendar month in which the 


exceedance occurred, the date, time and length of time that the parameters were 


exceeded, and the corrective actions taken or the preventative measures 


•

adopted to operate the facility within that operating parameter. 


e. 	 Records will be kept of any instances in which the pilot flame is not present in the 


enclosed combustor or the utility flare, the date and times that the pilot was not 


present and the corrective actions taken or the preventative measures adopted to 


increase the operating time of the pilot flame. 


f. 	 Records will be kept of any instances in which the thermocouple (or other heat 


sensing monitoring device) installed to detect the presence of a flame in the 


enclosed combustor or utility flare is not operational, the time period during which 


it was not operational, and the corrective measures taken. 


• 

Patricia Charging 2-15H Pad 12/29/11 pg.14 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


g. 	 Records will be kept of any time periods in which visible emissions are observed 

emanating from an enclosed combustor or utility flare. 

h. 	 Records will be kept of all required testing and monitoring. The records will 

include the following: 

i. 	 Date, place, and time of observations, sampling or measurements; 

ii. 	 Date(s) analyses were performed; 

iii. Companies or entities that performed observations and the analyses; 

iv. Analytical techniques or methods used; 

v. 	 Results of such analyses or measurements; and 

vi. Operating conditions as existing at the time of sampling or measurement. 

i. 	 Monitor the pilot flame using a thermocouple, and/or a chart recorder or other 

means that indicates the continuous ignition of the pilot flame; 

j. 	 A check of the chart recorder or other monitoring device to ensure proper 

operation will be done whenever an operator is on site; at a minimum, quarterly; 

k. 	 A check of the pilot flame to ensure proper operation will be done whenever an 

operator is on site; at a minimum, quarterly; 

I. 	 Measure one other parameter determined during the independent engineering 

analysis or provide a manufacturer or vendor guarantee; and 

m. 	Visually confirm that no smoke is present during operation of any enclosed 

combustor or utility flare whenever an operator is on site; at a minimum, 

quarterly. 

Dakota M 3 will follow, for each enclosed combustion device and utility flare, the 

manufacturer's written operating instructions, procedures and maintenance schedule to 

ensure good air pollution control practices for minimizing emissions. 

6.3 Produced Casing Head Gas Emergency Utility Flare 

Dakota-3 is not requesting any limits from the produced casing head gas because it is 

being sent to the gas sales pipeline. If a malfunction from the pipeline occurs and the 

gas cannot be sold, Dakota-3 will record the volume of gas sent to the emergency utility 

flare . 

During an emergency or malfunction Dakota-3 will route the produced casing head gas 

to the onsite utility flare that will be designed and operated to reduce the mass content 

of VOC (or VOC and HAP) emissions in the vapors vented to the device by at least 

98%. Dakota-3 will follow, for the utility 'flare, the manufacturer's written operating 

instructions, procedures and maintenance schedule to ensure good air pollution control 

practices for minimizing emissions. 

All vent lines, connections, fittings, valves, relief valves, or any other appurtenance 

employed to contain and collect vapors and transport them to the utility flare will be 

maintained and operated during any time the facility is operating. 

Patricia Charging 2-15H Pad 12/29111 pg. 15 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

The emergency utility flare will be: 

a. 	 Designed and operated in accordance with the requirements of 40 CFR 60.18 


and 40 CFR 63.11. 


b. 	 Designed to have sufficient capacity to achieve at least a 98% destruction 


efficiency for hydrocarbon volumetric flow and BTU content routed to the device; 


c. 	 Operated with a liquid knock-out system to condense any condensable vapors; 

d. 	 Equipped with a thermocouple to detect the presence of a pilot flame with a 


minimum accuracy of ±2 percent of the temperature being monitored expressed 


in °C, or ±2.5 °C; 


e. 	 Equipped with a recording device, such as a chart recorder or similar device, to 


document the presence of a flame; 


f. 	 Equipped with an electronically controlled ignition system with a malfunction 


alarm and remote notification system if the pilot flame fails; 
 • 

g. 	 Maintained in a leak-free condition; and 

h. 	 Operated in a smokeless mode. 

Monitoring Requirements: 

The monitoring requirements for the emergency utility flare will be the same as 

described above for the production storage tanks control device as specified in Section 

6.2. 

Recordkeeping Requirements: 

The recordkeeping requirements for the emergency utility flare will be the same as 

described above for the production storage tanks control device as specified in Section 

6.2. 

6.4 RICE Engines 

Depending on the size (hp) and date of manufacture, Dakota-3 is required to meet the 

emission standards set forth in 40 CFR 63 Subpart JJJJ or 40 CFR 60 Subparts 1111 and 

ZZZZ, as applicable. Dakota-3 will properly operate and maintain the engines as per the 

manufacturer's specifications to ensure compliance with the above standards. If the 

engines emissions are not certified to meet the required standards, Dakota-3 will have 


•

performance tests conducted on the engines as required by the applicable subparts. 


6.5 Natural Gas-Fired External Combustion Units 

Due to the insignificant emissions associated with the 0.5 to 0.75 MMBtu/hr natural gas 

(or propane) fired line-heaters, no monitoring or recordkeeping requirements are being 

proposed by Dakota-3. 

Patricia Charging 2-15H Pad 12/29/11 pg.16 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
6.6 Truck Loading 

The truck loading rack is designed for submerged filling of the tank trucks. This is 

standard operating procedure. 

Monitoring Requirements: 

The monitoring requirements for truck loading will be estimating the monthly VOC, total 

HAP, and any single HAP emissions from the load out operations using input 

parameters, equations, and emission factors from AP-42, Fifth Edition, Volume I, 

Chapter 5. 

, 

I 

• Recordkeeping Requirements: 

Total VOC, total HAP, and any single HAP emissions, in tons, from loading operations 

will be calculated and recorded at the end of each month, beginning with the first full 

calendar month after operations commenced. Prior to twelve full months of operation, 

Dakota-3 will, at the end of each month, add the emissions for that month to the 

calculated emissions for all previous months since operations commenced, where 

applicable, and record the total. Thereafter, Dakota-3 will, at the end of each month, 

add the emissions for that month to the calculated emissions for the preceding eleven 

months and record a new twelve-month total. 

Dakota-3 will keep all input parameters and calculations used to determine the monthly 

emissions. 

6.7 Fugitive Emissions: Equipment Leaks 

Dakota-3 will minimize leaks of volatile organics from each piece of equipment in 

hydrocarbon service at this facility. 

Work Practice and Operational Requirements: 

• 

a. At a minimum, Dakota-3 will detect and repair leaks at each tank thief hatch, 

centrifugal compressor vent, reCiprocating compressor vent, instrument, meter, 

diaphragm, pressure relief device, dump arm, open-ended valve or line, vent line, 

flange, connection, fitting, or any other appurtenance employed to contain and 

collect vapors and transport them. 

b. 	 Dakota-3 will make the first attempt to repair any leaking equipment within five 

days after the leak is detected. 

c. 	 Any leaking equipment will be repaired as soon as practicable, but no later than 

15 days after the leak is initially detected, unless the repair is technically 

infeasible without a facility shutdown. Such equipment will be repaired before the 

end of the first facility shutdown, after the leak is initially detected. Dakota-3 will 

make the first attempt to repair any leaking equipment within five days after the 

Patricia Charging 2-15H Pad 12/29/11 pg. 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

leak is detected. Oakota-3 will minimize leaks of volatile organics from each 


piece of equipment in hydrocarbon service at this facility. 


Monitoring Requirements: 

a. 	 Oakota-3 will conduct leak detection monitoring on a semi-annual basis. If no 


instrument reading of 10,000 ppm or greater is measured for two consecutive 


semi-annual monitoring periods, the required monitoring frequency will change 


from semi-annual to annual. If any single instrument reading of 10,000 ppm or 


greater is measured, the required monitoring frequency will change back to semi­


annual. 


b. 	 Oakota-3 will use one of the following methods to conduct leak detection of the 


equipment: 


i. Method 21 • 

a} Use the equipment leak detection methods in 40 CFR Part 60, 

Appendix A-7, Method 21; and 

b} If an instrument reading of 10,000 ppm or greater is measured, a leak 

is detected. 

ii. 	 Optical Gas Imaging Instrument 

a) 	Use an optical gas imaging instrument for equipment leak detection in 

accordance with 40 CFR Part 60, Subpart A, §60 .18(i)( 1) and (2) of the 

Alternative work practice for monitoring equipment leaks; 

b} Any emissions detected by the optical gas imaging instrument are a 

leak unless screened with Method 21 (40 CFR Part 60, Appendix A-7) 

monitoring, in which case 10,000 ppm or greater is designated a leak; 

c} The optical gas image will include an image of the equipment in 

addition to any observed leaks; and 

d} The optical gas imaging instrument will be operated in accordance with 

the instrument manufacturer's operating parameters. 

iii. 	 Operator Developed Inspection Protocol - Best Management Practices 

a} Develop and use a written inspection protocol approved by EPA, 

based on best management practices, for leak detection; 

b) 	Any emissions detected by the protocol are a leak unless screened 

with Method 21 (40 CFR Part 60, Appendix A-7) monitoring, in which 

case 10,000 ppm or greater is designated a leak; 

c) 	 The protocol will include the following: • 

I. 	 A detailed description of the best management practice to be 

used for leak detection; 

II. 	 A requirement to use a log book that contains a list, summary 

description, or diagram showing the location of all equipment in 

hydrocarbon service at the facility, and the required 

recordkeeping for equipment leaks; and 

III. 	 A requirement that the log book be Signed by the inspector at the 

completion of each inspection. 

Recordkeeping Requirements: 

Patricia Charging 2-15H Pad 12/29/11 pg.18 


NSR Synthetic Minor Permit Application 


Project #: WEP211324 


• 
• 


a. 	 Dakota-3 will document and maintain a record of each leak detection inspection 

and repairs. 

b. 	 All leak detection inspection records will include, at a minimum, the following 

information: 

i. 	 Date of the inspection; 

ii. 	 All documentation and/or images produced in the inspection; 

iii. 	Findings of the inspection; 

iv. Any corrective action taken; and 

v. 	 Inspector's name and signature. 

6.8 General Recordkeeping Requirements 

• Total vec {or vec, total HAP, and any single HAP) emissions, in tons, from each piece 

of equipment will be calculated and recorded at the end of each month, beginning with 

the first full calendar month after operations commenced. Prior to twelve full months of 

operation, Dakota-3 will, at the end of each month, add the emissions for that month to 

the calculated emissions for all previous months since operations commenced, where 

applicable, and record the total. Thereafter, Dakota-3 will, at the end of each month, 

add the emissions for that month to the calculated emissions for the preceding eleven 

months and record a new twelve-month total. 

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

system to monitor and record the needed data. SCADA consists of computer systems 

that monitor and control industrial. infrastructure. or facility-based processes. The 

system may include, but is not limited to. production monitoring, electronic pressure 

indicating transmitters. pilot flame status monitoring, valve position setpoints, 

temperature monitoring. alarm notification. data logging, flowmeter monitoring, etc. 

• 


Patricia Charging 2-15H Pad 12/29/11 pg.19 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

7.0 QUALITATIVE AIR QUALITY ASSESSMENT 


The climatology and air quality of the area of interest is dominated by continental air 

masses with only minor terrain features (from a synoptic point of view) of interest. The 

area has excellent ventilation since large air mass movement is not limited by any 

significant geologic features. This is in stark contrast to other areas in Region 8 that 

may have limited atmospheric mixing due to mountain valleys or large mountain ranges 

that can minimize the effect of air mass movement. 

Ambient air quality data has been gathered in and near the reservation for many years. 

The results of that ambient monitoring network indicate ambient concentrations of all 

pollutants well below the National Ambient Air Quality Standards (40 CFR 50). Those 

measured values include the impact of substantial oil and gas development that has 

occurred in the region including development near the proposed facility. In fact, much of 

the monitoring data yields background values despite the presence of current industrial 

activity and general anthropogenic sources. The reported data shows that the values 

are the same or nearly the same as one would find in a rural location devoid of any 

industrial activity (although industrial activity is clearly nearby). 

A typical facility's actual emissions are modest in nature (i.e., below typical permitting 

thresholds) as demonstrated in Figure 2; therefore. additional ambient impact analysis 

is not warranted. 

• 

• 

Patricia Charging 2·15H Pad 12129/11 pg.20 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


8.0 ENDANGERED SPECIES ACT 


The Endangered Species Act (ESA) requires EPA, in consultation with the U.S. Fish 

and Wildlife Service (USFWS) and/or the NOAA Fisheries Service, to ensure that 

actions EPA authorizes are not likely to jeopardize the continued existence of any listed 

threatened or endangered species (TES) or result in the destruction or adverse 

modification of designated critical habitat of such species. 

TES are considered to be those species recognized by the USFWS as listed or 

proposed species, and those designated as candidate TES under the ESA. Whether 

critical habitat for TES exists near the facility will first be assessed by consulting the 

USFWS North Dakota Ecological Service Field Office website 

(http://www.fws.gov/northdakotafieldoffice/index.htm) and noting the potential 

occurrence of each TES by county. Once the potential presence of a species is 

assessed, a look at whether any critical habitat exists in the vicinity of the facility will 

help determine the possibility of any impacts from the facility on TES. EPA will conduct 

an evaluation of the potential for TES impacts from the facility and consult, as 

appropriate. with USFWS regarding identification and mitigation of any impacts. 

• 


• 


Patricia Charging 2·15H Pad 12/29/11 pg.21 

NSR Synthetic Minor Pennit Application 

Project#: WEP211324 

• 
• 

9.0 NATIONAL HISTORIC PRESERVATION ACT 


The National Historic Preservation Act requires EPA, in consultation with State and/or 

Tribal Historic Preservation Officers, to ensure that actions authorized are not likely to 

affect cultural resources. 

The potential for cultural resources in the vicinity of the facility will be assessed by 

consulting with the North Dakota State Historic Preservation Office (NDSHPO) and the 

Tribal Historic Preservation Officer(s), and conducting a literature review of available 

information from the area immediately surrounding the facility 

(http://history.nd.gov/hp/siclass1.html). If the review finds a need for more intensive 

analysis of the immediate area of the facility. a Class II or III cultural resources inventory 

may be performed as required. EPA will conduct the consultation with NDSHPO and 

Tribal officials to identify any cultural resources that could be impacted by the facility 

and any needed mitigation measures for those impacts. 

• 

• 

Patricia Charging 2-15H Pad 12129/11 pg.22 

NSR Synthetic Minor Pennit Application 

Project #: WEP211324 

• 
• 

ATTACHMENT B: EMISSION INVENTORY 

• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 
 • • 

Fac!IIty_lnformation 

Patricia Charging 2-15H Pad 

,a.ssociated Wells: 

Patricia Charging 2-1SHC. 2-15HO 

Not Producing Yet 

!U8IJI 

BOPO 965 , DracIucIIon III ......of01 .......on'" pNdIcIod lint 3G dovI dI productlo.. 

Mscfd 671 ~...,... ddv prod_",_III Moc:I ....dIr. bMod on'"pnldlclld lint 3G dovI dI production. 

• 


GREEN. Requires Input 


RED =No input required. This is a calculated value.
 b·.._......·_· 	 ;...IInt..... ",prod_or........",lIIOdIIIcIIIoIIdI ......,. 
 I


Input Data 

Dal<ota-3 EIP Com~an~, [LC 


Decline Factor 0.530 dod.......... ""...1Int ,...-ofopondloll. on ..... 1rom pnMoUllyproduclng ..... III ....-fIoId and Iorrnollon. 

i'djusted BOPO 512 1Th....... clio....BOPO -"'lIDIII prod"'" wing ......._ .... docIIN ....... 

:Adjusted Produced Gall (Mscfd) 356 irhII_........... mcfllofSJM_.........--..ID~ wing'" .............dod........... 

OlllCondeneate Tank Date 	 Description '*......... down IIIIIIU ID chooM ... __W g_ moIhod. Flash Gas Method: Prooess Simulator 

Process Simulator Estimated IICflbbl 40.23 1'''...fjbbllrom''-_lIIIIIIIIor~ ...1o. ~on ~EII'TonkEmIoo'" su""",oyOuq,Ul 

Estfmeted Tank Vapolll (acfd) 20687.28 1Ib.......1IIlIMIod tcId ofllllk_" bModon ...foIowIng: ........ BOPO Iftu....... by'" tcMIbl ......... on Unt .. 

Lower Heatlna Value 2401.97 '-'>-hoIIfng .....(hftoIIdlllnk_".S-on __EII'T.nkEmioolonllum...ryOuq,Ul 

Molecular Weight 42.14 [MoIoculorwolglttof ...llllk_1npoundo pofpolllllkdl ~II~ lIMN on __Ell' Tift. EmIl.... Summory 0tJIput. 

VOC% 74.026 rvoc wooIgIttfrocllon "'...IIIIk_r_(C3+). ~.n ""'_ESP Tonk Emiooion Summory Ouq,Ul 

VOC TPV/BOPD Emission Factor 0.613 lIMN .. Ell' Tonk e_1lum1lllllY Ouq,ut. {Su""""" OUCpIll,,_.1_......noblp b_TPY and BOPIll 

HAP% 1.046 '"'woIgIttfrocllon dI...llllk_r_. on __Ell' Tlflkem...... SUlftmooy 0tJIput. 

HAP TPYIBOPD Emission Factor 0.009 on 11""",,,-_ Ell' Tank £mIooloo SumllllllY OUCpUl (Su""""" OUCplllc_. __ NlItIonahip _ TPY In<! BOPO) 

C02% 0.26% !CO2 woIgIttfrocllon "'...lInk ___• lIMN on __ElP T.nk EmIooloo S....mooy Ouq,ut. 

H4wo1g1ttfrocllondl...llllk ___.IIMN •• __EIPT...kE.....ionS....mooyOuqoUl CH4% 	 1.99% 

H2S_lght% 	 0.09% WIIgIIt,.,.,..mdl"'lInk_r....IIMN"" __Ell' T...k EmIl.... s .... mooy Output. 

~Smole% moll,.,.,..m "'...lInk __ ....lIMNon """__Ell' T.nk EmIooIo. Surnmory Ouq,ut. 0.10% 

Enclosed Smokeless CombuslDr '*... chpdownllllllUlDc'-...___ion......nl""'"

Control Destruction Efficiency 	 98% !Control oIIIcloncy of..,. ............ oonImIo. ThllII. ftIOId .........bMod on......nl""'" 

• • 

Oakota-3 E&P Company, llC 

Input Data 

GREEN = Requires input 

FacllltylnformatJon RED • No Input required. This II a calculated value. 

Patricia Charging 2·15H Pad 

Associated Well .. : 

Patricia Charging 2.15HC. 2·15HO Loflht~...Iht...O"""" 

Treater Gal Date Descrlotlon I 

Btu/set 1700.39 lltullCfo,.............. (Ftom "",_tIoIdpilltOlyoltl I 

Molecular Weight 29.65 ......mo__woIghIoflht"""""pllII~.(F_ ..p_fIoldpl...IyoIl, I 

Specific Gravity 1.02 II-..y"_rllIf*I"c amt!¥10 ..............Ight, _.Iht IIf*I"cg'"""oflht ..........pl. tF"'M __tIoIdpilltOlyolt) 

Average Molecular Weight 29.65 "'_ ..,,-fIoId._ onoIyoool 

VOC% 45.94% vae woIghIfnIcIIon of Iht..........pitNoIa: Wtlglrt%. nDI M%'Ao~ (From __fIold ._IItOIyoIt) 

HAP% 1.28% ~p woIghIfnIcIIon oflht.............. tNoIa: WIIighf.%. nDI M%'Ao). (F... m ""'_tIoId pllnoIyoll) 

C02% 0.863% C02wo1gh1fn1c11on o!lht~pI. (NoIII:WIIighf.%. nDlM%'Ao~ (F- "",_fIolI! pllItOIyoll) 

CH4% 25.747% CH4 woIght rr.:tIon of Iht wtIIIIrulll .... tNoIa: w.1gIft. nDI MoII%~ (Fn>m "",NI_tIoId pllItOIyolt) 

H:.S weight % 

H:.S mole % 

O.OOO"k 

0.000% 

IItSwoIghtpooanto!lht~ .... IF"'M"",,_,_fIoIdpilltOlyolll 

1ItS .......-.toflht~ .... tFn>M"",_fIoldpilltOlyoltl 

Connected to ..les line UNlhtdropdown ......... <'-Iht"""""'__......nfIIlI~ 

Contro/lCapture Ellk:lency 100% rouItNI*, plpol...--.11_0IpIUn ofpl. '1Ionod, _11IIIIcIIMo:y 01..., oppIIcIb" 00fttnIIe lcomb-. plllo..,uIIIIIy 1Io... 11I:~ 

Treater Bumer(l) DeacrtDtlon 

Talal Btulhr 1500000 lI'olIIbu_IlIIIna",lhthullrtrMlorburMrfl,lnll4ulhr••Iht..........bu......lddlht_hutlnput....-. 


Hours of Operation 
 8,760 !Tho b""""'.j ....--.I.. __1,710 hotIrt ..... _. 

Truck loading DeacrlDf;lon 

Oil II sold Ihrouah LACT UNIht droll down ....... *,<'-tIIt _ ...... 011 ...IMIhod. I •• "1OId 1MIugh. LACT no Input"....._1Nd 10 u... JO.U. 


Submerged loading: dedicated normal service 
 0.6 	 UN Iht ...... down IIotlochooulht _ ...... modoof~ Tho -.aottfllDrwll bt MIoo1Iod bINd on modo '"ope_.

Molecular Weight MoIocuIotwolghlofllllltwpo.. ln ........... __............woIght _ fIolhlng __'"'"'''''''''- ElP Tlnko_ 42.14 

Vapor Pressure 2.30 

Temperature SO.OO "'buIk ..... Id,......InFahnnhllt.rno ....pecIIc_.......... _ ..........._-....~

Load Rate (bbllhr) 180 '"'* ....ofliquid IHdod In btrNII ..... hour. 

Load Time (hrs) 1.00 	 !Tho ....ItIl...1D 1NdoIII_1oId (h",~ 

• 

IPriiiiimatICPumpe and CoIitOlJera(None) 

IGIycOI Dehydrator (None) 

• 

..... ","- Inchobtolulo IPoW. no ..........._ ......................." 1ob1o 20. Truckl.oldlng lib. 
• • 

nDakota-3 E&P Com~anYI LLC II 


• 


FaclHtY: 

Patricia ChIlrglng 2·15H Pad 

IAssociated Wei,.: 

IPatriCIa Charging 2.15HC. 2­

1'5HD 

OillCondensate Tanks 

CasillQ Head Gas 

Treater Surner 

RICE Engine 

Truck loadillQ 

Fuel Storaae Tank 

Pneumatic PumD 

Pneumatic Controllers 

GlYCOl DehYdrator 

ITotals !'!P:!l 

OillCondensate Tanks 

casing Head Gas 

Treater Burner 

RICE EIlQine 

Truck loadillg 

Fuel Sioraae Tank 

Pneumatic PumD 

Pneumatic Controllers 

Glvcol Dehydrator 

ITotals (TPY) 

VOC 

313.49 


4.67 


0.04 


2.27 


NIA 


Nl!gIigibie 


NIA 


NIA 


N/A 


320.46 

voc 

6.27 

4.67 

0.04 

2.27 

N/A 

Nealiaible 

N/A 

N/A 

NlA 

13.24 

Uncontrolled Potential to Emit 

Criteria Pollutants 

HAP NOx PM PM10 PM2.$ 

4.37 NIA NIA N/A N/A 

0.13 0.75 0.05 0.05 0.05 

0.01 0.64 0.05 0.05 0.05 

3.40E-02 8.70 0.05 0.05 0.05 

NlA NlA NIA N/A N/A 

Negligible N/A N/A NIA N/A 

NlA N/A N/A NIA N/A 

N/A NIA N/A NfA NlA 

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

II 4.55 I I 10.09 I I 0.15 I I 0.15 I I 0.15 

HAP 

0.09 


0.13 


0.01 


3.40E-02 


NlA 


Nealiaible 


NlA 


NIA 


NlA 


NOx 

0.61 

0.75 

0.64 

8.70 

N/A 

N/A 

N/A 

NIA 

N/A 

Emission Summary 

Allowable Potential to Emit 

PM 

0.03 

0.05 

0.05 

0.05 

N/A 

N/A 

N/A 

NIA 

N/A 

0.26 10.71 0.18 I I I I I I 

Criteria Pollutants" 

PM10 

0.03 

0.05 

0.05 

0.05 

NlA 

NlA 

N/A 

N/A 

N/A 

0.18 

PM2.5 

0.03 

0.05 

0.05 

0.05 

NfA 

N/A 

NIA 

N/A 

NlA 

0.18 

I I 


I I 


CO 

NIA 

4.09 

0.54 

14.36 

N/A 

N/A 

NIA 

N/A 

N/A 

18.99 

CO 

3.34 

4.09 

0.54 

14.36 

NIA 

N/A 

NIA 

NlA 

NIA 

22.33 

I I 


I I 


H2S 


N/A 


NA 


NIA 


NIA 


N/A 

N/A 

NIA 

N/A 

NIA 

0.00 

H~ 

N/A 

0.00 

N/A 

N/A 

NfA 

N/A 

N/A 

N/A 

NIA 

0.00 

I I 


I I 


502 

NIA 


0.00 


0.00 


4.14E-02 


N/A 


N/A 


NIA 


N/A 


N/A 


0.05 

502 

N/A 


0.00 


0.00 


4. 14E-02 


N/A 


N/A 


NIA 


NlA 


NIA 


0.05 

• 


HCHO 

Negligible 

0.00 

Negligible 

0.03 

Negliaible 

N/A 

Negligible 

Negligible 

Nealiaible 

I I 0.03 

HCHO 

Negliaible 

0.00 

Nealiaible 

0.03 

Nealiaible 

N/A 

Nealioible 

NealiQible 

Negligible 

0.03 

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

CH, H2O 

Oil/Condensate Tanks 8.31 0.01 

Casina Head Gas 2.62 0.00 

Treater Bumer 0.04 0.01 

RICE Enaine 0.11 0.02 

Truck Loadina 0.00 N/A 

Fuel Storaae Tank N/A N/A 

Pneumatic Pump N/A NlA 

Pneumatic Controllers N/A N/A 

GIvcoI DehYdrator N/A NIA 

2087.07 

2155.25 

No 

Facility: nOakota-3 E&P Com~any, LLC I] I Patricia Charging 2·15H Pad 

AHoclated W.".: 

Pa1r1cla ChIll'lJI"9 2·15HC. 2· 

15HD 

Potential To Emit Actual 

Greenhouse Gasesb Greenhouse Gasesb 

CO2 H2O CO2 CH, 

N/A N/A 451.97 0.00 

783.65 0.00 783.65 2.62 

772.94 0.01 772.94 0.04 

7.57E+01 0.02 7.57E+01 0.11 

0.00 NIA 0.00 0.00 

NIA N/A N/A NlA 

N/A NIA NIA N/A 

NIA N/A NlA NIA 

N/A NfA NIA NlA 

'Totals (TPy) I I 1632.29 II 11.08 II 0.03 I I 2084.26 I I 2.77 I I 0.04 I 

OHG M••• E......lon. (Ipy): I 1843.41 I GHG Mass Emission. (tpy): 

C02·11py): I 1875.11 I C02e IIpy): 

Applicable to the r.IIOri119 Rule?: 

-, 

• 

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

• 

• 
 • • • 

[ Dakota-3 E&P Company, LLC I 

Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia ChargiI'lQ..2·15HC. 2·15HO 


Tanks 

Oil Production! 512 BOPO 


Flare Gas VoIume[ 20.587 --sa7daY] 


Lower Heating Value! 2401.97 Blulscf 

Molecular WeightC -42.14 - IDJIl:Hi1Ole) 

VOC wt FractionC 14]13%­

VOC Emission Factor[-0:613--tpYTbOpd' 

HAPs: 

Benzene wt Fraction 0.0285% I 

Toluene wt Fraction 0.0166% I 

E-Benzene wt Fraction 0.0033% I 

Xylene wt Fraction 0.0191% I 

n-Hexane wt Fraction 0.9045% I 

2.2,4-Trimethylpentane ..... -.:-p'=-'_" 

wt Fractionl 0.0739'14 

HAP Emission Factor[ -o:ooa- - iPedl 

C02 wt Fraction[ 0.26% 

CH4 wt FractionC -;L~ 

Controlled emissiOns are calculaled based on a ~deslruction efficiency of the voe gas 
• • 

r Dakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charaino 2-15HC, 2-15HD 


Tanks 

CRITERIA POLLUTANT EMISSIONS8 

Uncontrolled VOCs (PTE): 

Using E&P Tanks Run: I 0.613 TPV VOC/BOPD I x 511.74 BOPO x I 

ORE 

0% 313.49 TPvl 

Controlled VOCs (Allowable): 

USing E&P Tanks Run: I 0.613 TPV VOC/BOPO I x 511.74 BOPO x I 

ORE 

98% 6.27 TPvl 

Uncontrolled HAPs (PTE): 

Using E&P Tanks Run: wt% 

Benzene 858 scflhr 

858 scflhr 

858 scflhr 

858 scflhr 

858 scflhr 

858 scflhr 

x 1/379 scfllb-mole 

1/379 scfllb-mole 

1/379 scfllb-mole 

1/379 scfllb-mole 

1/379 scfIIb-moIe 

1/379 scfflb-mole 

x 42.14 Ibllb-mol 

42.14 Ibllb-mol 

42.14 Ibllb-mol 

42.14 Ibllb-moI 

42.14 Ibllb-mol 

42.14 Ibllb-mol 

E-Benzene x x x 

x ~ 

Toluene x x x ~ 

n-Hexane x x x ~ 

Xylene x x x ~ 

~ 

2.2.4-T rimethylpentane x x x ~ 

ORE TPY 

0% 

0% 

0% 

0% 

0% 

0% 

0.031blhr 

0.00 Iblhr 

0.021b1hr 

0.861b1hr 

0.021b1hr 

0.071b1hr 

x = .. 0.12

x = 0.01

.. 

= x = 0.07

x = 3.78

.. 

= x 0.08 " x = .. 0.31

Benzene 858 scflhr 

858 scflhr 

858 scflhr 

858 scflhr 

858 scflhr 

858 sctlhr 

x 11379 scfllb-mole 

11319 scfllb-mole 

1/319 scfllb-moIe 

11319 scfllb-mole 

1/379 scfllb-mole 

1/379scfllb-mole 

• 

Controlled HAPs (Allowable): 

x 42.14 Ibllb-mol 

42.14 Ibllb-mol 

42.14 Ibllb-mol 

42.14 Ibllb-mol 

42.14 Ibllb-mol 

42.14 Ibllb-mol 

x 

E-Benzene x x x

Toluene x x x

n-Hexane x x x 

Xylene x x x

2.2.4-Trimethylpentane x x x

• 

"'ii.ii3% 

~ ~ 

~ 0.02% 

~ 

Uncontrolled TOTAL HAPS (TPV) = I 4.37 

98% 

98% 

98% 

98% 

98% 

98% 

x O.OOlblhr 0.00

O.OOlblhr 

O.OOlblhr 

0.021blhr 

O.OOlblhr 

O.OOlblhr 

= = x = .. 0.00

x = 0.00 " x = = 0.08

x = .. 0.00

x .. 0.01 " 

Controlled TOTAL HAPS (TPV) .. 0.09
• • • • 

[ Dakota-3 E&P Company, LLC 


Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia Charging 2·15HC. 2·15HD 


[ hn~ 

Uncontrolled NOx: 

Nox:l 0 scflhr x I 2,402 Btulscf I 

0.00 Iblhr 

)( 

x 

1 MMBful1,OOO.OOO Blu 

8760 hr/~ x I 

x I 0.068 IbIMMBtu I 

1 lonI2OOO Ib 

0.00 

0.00 

Iblhr! 

TPV I 

NOx Created by Combustion (Actual) 

NOx:1 858 scflhr x I 2,402 Bfulscf 1 

0.14 Ibi&] 

x 

x 

1 MMBlul1,OOO.OOO Btu 

8760 hr/~ x ! 

x I O.068lb1MMBlu I 

1 lonI2OOO Ib 

0.14 

0.61 

lbihr 1 

TPV I 

Uncontrolled PM: 

PM:l 0 scllhr x I 7.6 

0.00 

1b/1.000.000 sci 

Iblhr x 8760 hr!l!; 

0.00 

x 

lbihr 

1 lon/2000 Ib 0.00 TPY 

PM Created by Combustion (Actual) 

PM:! 858 scf/hr x I 7.6 

0.01 

Ib/1.000,OOO sef 

Iblhr I x 8760 tlrlyr _ 

0.01 

1 )( 

Iblhr 

!1-'on~lb ] I~_TPY:J 
• • 

I . Dakota-3 E&P Company, LLC 


Patricia Charging 2-1SH Pad 


Associated Wells: 


Patricia ChaI"Qi.rlQ..2-1SHC, 2-15HD 


Uncontrolled CO: 

co:1 0 scflhr I )( I 2,402 

I 0.00 

Btu'Scfl 

Iblhr I 

x 

)( 

I 

I 

1 MMBtu'1.000.000 Btu 

8760 hrl:e; I x 

I 

I 

)( I 0.370 IblMMBlu I 

1 Ion12000 Ib I ::: 

::: I 0.00 

I 0.00 

Iblhr I 

TPY I 

CO Created by Combustion (Actual, 

CO:1 858 scflhr I )( I 2,402 BllO'scfl )( I 1 MMBtu'l.000.000 Btu I x I 0.370 IblMMBtu I ::: I 0.76 Iblhr I 

I 0.76 Iblhr I )( I 8760 hr!:e; I )( I 1 tonl2000 Ib I ::: I 3.34 TPY I . 

NOx. S02. and CO emission factors are from AP·42 Table 13.5·1 

(Emission Factors for Flare Operations) . 

• 

I Tanks - I 

• 

• • • • 

I Tanks _._. --] 

Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


PatriCia Charaing 2-15HC. 2-15HD 


REGULATED GREENHOUSE GAS EMISSIONSb 

Uncombusted CO2: 

C02:1 858 scflhr x 111379 scf/lb-mole I x 

0.25 

42.14 1Mb-moleI 

Ib/hr x 

WI 

x 10.26% I 

8760 hr/t!; x I 

ORE 

x 0% 

1 1onJ2000 Ib 

0.25 

1.10 

Ib/hr 

TF'Y 

C02 Created by Combustion (Actual) 

c02:1 858 scflhr x ,'20.000.0 Ib/1.000.000 sef 

1~2.94 ---.lblh~ I x L.876~_] 

102.94 Iblhr 

x C1 ton/@QjiQ I 450.86 TF'Y 
• • • • 

Uncontrolled CH4: 

CH.:I 858 --scfihr 1 x [1/319 scf/lb-mole I x [4L!:rlMtHnOt!l x 

wt 

11.99% I 

ORE 

x 0% 1.90 lblhr -­ J 

1.90 Iblhr x 8760 hrlyr x I 1 ton/2000 Ib ;:: 8.31 TPY ::J 

Controlled CH4: (Actual) 

CH4:1 8511­ -scf7hr J x 11/379 scf/lb-mole 1 x 42.1r Ib7ItHnOle! x 

wt% 

11.99% I 

ORE 

x 98% 0.0. Ib/hr J 

0.04 Iblhr x 8160 hrlyr x I 1 tonl2000 Ib 0.17 TPY ] 

Dakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia ChllrgLng2-15HC. 2-15HD 


Tanks 
• • • 


[ Dakota-3 E&P Company, LLC 


• 


Tanks I 

Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia Cha19il'lg 2·15HC. 2-15HD 


Uncontrolled N20: 

CH4:1 858 scflhr x 11/379 scfllb-mole 1 x 

0.00 

42.14 Ibllb-molel 

Ib/hr x 

wt% 

x 10.00% I 

8160 hr1f x I 

ORE 

x 0% 

1 tonl2000 Ib 

0.00 

0.00 

Ib/hr 

TPY 

N20 Created by Combustion: 

CH4:1 858 scf/hr x I 2.3 Ibl1,OOO.OOO sef 0.00 Ib/hr 

0.00 Ib/hr x 8760 hrl~ x 1 1011/2000 Ib 0.01 TPV 

C02 and N20 emission factors are from AP-42 Table 1.4-2 

(Emission Factors for Natural Gas Combustion). 
• • • • 

Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Chargil1g 2-15HC. 2-15HD 


Flare Gas Volume[ 1,483 scflhr !(Takes into account the 10% of the total 

produced gas volume that is not being sold.) 

Lower Heating Valuer I -1~7~00~.-=3~86~5=7:'!"1--:B""tu""lf!'"scf""'"-" 

Avg. MolecularWeight!'-~65---'~ 

VOC wi fraction! - 45.94% 

HAP wi fraction 

Benzene wi fraction 

E·Benzene wi fraction 

Toluene wi fraction 

n-Hexane wi fraction 

Xylene wi fraction 

1.28% 

0.15% 

0.01% 

0.18% 

0.84% 

0.10% 

Casing Head Gas-I 

2,2,4-Trimethylpentane..-_-=-::::-_--, 

wi fractlonl 0.00% 

C02 wi fraction! ~O-:n%- J 

CH4 wi fractlonl- 25.75%~ J 

Hours of Flaring frni 8760 hourslyr PTE:.IL_________ 

Control Effllcienc' 98% ORE 
• • • •


,,,..#J~'~ 

[ Dakota-3 E&P Company, LLC 

Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-15HC. 2-15HD 


- - - - - - - - - - -Casing Head Gas - - - - - - - -I 

CRITERIA POLLUTANT EMISSIONSa 

Controlled VOCs (PTE): 

voe:1 1.483 scflhr x 111379 scfltb-mole x 

1.07 

129.64686 Ibllb-mole , x 

Iblhr x 8760 hrl~ 

wt% Conlml% 

45.94%1 x 1 98% 1 

x 11 tonl2OOO Ib 

1.07 Iblhr 

4.67 TPV 

Controlled VOCs (Allowable): 

voe:, 1.483 scflhr x 111379 scfltb·mole x 

L 1.0] 

129.64686 Ibllb-mole 1 x 

-'b/Il'- _I x 1_8760~_J 

wt".4. Conlml% 

45.94%1 x 1 98% 1 

x htonl2000 1"-_' 

1.07 Iblhr 

_4.67_TPVJ 
Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Cha!9!rut ~15tiC, 2-15HD 


Casing Head Gas 

Controlled HAPs (PTE): 

Using E&P Tanks Run: 

Benzene 1,483 scflhr x 

E-Benzene 1.483 seflhr x Toluene 1,483 scflhr x 

n-Hexane 1,483 scflhr x 

Xylene 1.483 sef/hr x 2.2.4·Trlmethytpentane 1,483 scflhr x Formaldehyde 1,483 seflhr 

Controlled HAPs (Allowable): 

Using E&P Tanks Run: 

Benzene 1,483 scflhr x E-Benzene 1,483 sef/hr x Toluene 1,483 scflhr x 

n-Hexane 1,483 seflhr x 

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

Formaldehyde 1.483 scflhr x 

• • 

1/379 scfllb-mole 

1/379 scfllb-mole 

1/379 scfllb-mole 

11379 scfllb-mole 

11379 scfllb-mole 

11379 sefllb-mole 

7.50E-02 IblMMsef 

I 0.03 

1/379 scfltb-mole 

11379 scfflb-mole 

11379 scf/lb-mole 

1/379 scfflb-mole 

11379 scfflb-mole 

1/379 scf/lb-mole 

7.50E-02 IblMMscf 

I 0.03 

x 29.64686 Ibllb-mol x 

x 29.64686 Ibllb-mol x 

x 29.64686 Ibllb-mol x 

x 29.64686 !bllb-mol x 

x 29.64686 Ibllb-mol x 

x 29.64686 Ibllb-mol x 

tblhr I x I 8760 hr!f; I 

x 29.64686 Ibllb-mol x 

x 29.64686 Ibllb-mol x x 29.64686 Ibllb-mol x 

x 29.64686 Ibl1b-mol x 

x 29.64686 Ibllb-moI x 

x 29.64686 Ibllb-mol x 

x 1000000 scf/MMsef 

Iblhr I x I 8760 hr/yr I 

wt% Control % 

0.15% x 96% 

0.01% x 98% 

0.18% x 98% 

0.84% x 98% 

0.10% x 98% 

0.00% x 98% 

x 11 tonl2000 Ib I 

wt% Control % 

0.15% x 96% 

0.01% x 98% 

0.18% x 96% 

0.84% x 98% 

0.10% x 98% 

0.00% x 96% 

x 11 tonl?OOQlb I 

• 

TPY 

= O.OOlblhr = 0.02 

= 0.00 !blnr . 0.00 

= 0.00 !b/hr = 0.02 

" 0.021b1hr = 0.09 

" 0.00 Iblhr = 0.01 

" 0.00 Iblhr .. 0.00 

" 0.00 Iblhr = 0.00 

" I 0.13 TPY I 

TPY 

" 0.00 Iblhr .. 0.02 

" O.OOlblhr • 0.00 

" 0.00 Iblhr = 0.02 

= 0.021b1hr " 0.09 

'" 0.00 Iblhr .. 0.01 

'" 0.00 !blhr = 0.00 

" 0.00 Iblhf " 0.00 

" L 0.13 TPY I 

• 
• • • • 

Oakota-3 E&P Company, LLC , 


Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia Charging 2·15HC. 2·15HD 


Casing Head Gas 

Uncontrolled NOx (PTE): 

Nox:1 1,483 setlhr x 1 1.700 Stu/scr 

0.17lblhr 

x 

x 

1 Mmbtu/l.000.000 Btu 

8760 hr!l!; x 

x 0.068 IbIMMStu I 

1 tonl2OOO Ib 

0.17 Iblhr 

0.75 TPY 

NOx Created by Combustion (Actual): 

Nox:1 1,483 setlhr x 1 1,700 Stu/set 

0.171b/hr 

x 

x 

1 Mmbtu/l.000.000 Btu 

8760 hrlyr x 

x 0.068 IblMMStu 1 

1 tonl2000 Ib __ I 

= 0.17 Ib/hr 

_0.7j_TPyJ 

Controlled H2S (PTE): 

H.s:1 1,483 setlhr x 111379 scfllb-mole x 

0.00 

129.64886 IbJlb-mole 1 

Ib/hr x 

x 

8760 hr/~ 

wt% Conlrol% 

0.00%1 x I 98% 1 

x 11 to",2000 Ib 

0.00 

0.00 

Iblhr 

TPY 

Controlled H2S (Actual): 

H.s:1 1,483 scrlhr x 11/379 scfllb-mole x 

0.00 

129.64686 IbIlb-mole 1 

Iblhr x 

x 

8760 hr!l!; 

wt% Control % 

0.00%1 x I 98% 1 

x 11 10012000 Ib 

0.00 

0.00 

Ib/hr 

TPY 
• • • • 

Oakota-3 E&P Com LLC 

Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-15HC. 2-15HD 


S02 Created by Combustion (PTE): 

5~~--sctlhr J )( 111379 scfAb·mole x 

0.00 

129.64686 IMb-mole 1 

Ib/hr x 

x 

8760 hrtyr 

wt% Control % 

0.00%1 x I 98% 1 

x (!Jiii7¥OOO Ib0.00 

0.00 

Ib/hr 

TPY 1 

S02 Created by Combustion (Actual): 

5021 1.483 scflhr] x 111379 scfAb·mole x 

0.00 

129.64686 1Mb-mole 1 

Iblhr x 

x 

8760 hrtyr 

wt% Control % 

0.00%1 x I 98% I 

x 11 tonl2OOO Ib - 1 

0.00 

0.00 

-iblhr 

TPY 

Casing Head Gas ] 

CO Created by Combustion (PTE): 

CO:C1/!3--sCfIhr] x 1 1.700 Btu/scf I 

r:::o:931b7hr:J 

x 

x 

1 Mmbtu/1,OOO,OOO Btu 

8760 hrtyr x 

x 0.3701bIMMBtli I 

1 tonl2000 Ib 

0.93 

4.09 

Iblhr-­ I 

TPY:J 

CO Created by Combustion (Actual): 

CO:I 1.483 scIlhr J )( 1 1,700 Btu/sct I x 1 Mmbtu/1,OOO,OOO Btu x 0.3701b1MMBtli I 0.93 Iblhr:J 

CO:-93lbihr] x 8760 hrtyr x 1 tonl2000 Ib ••09 TPY 1 
• • • • 

NOx. S02, PM, & CO emission factors are from AP-42 Table 13.5-1 and Table 1.4·2 

(Emission Factors for Flare Operations and Natural Gas Combustion). 

Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-15HC. 2-15HD 


Casing Head Gas 


PM Created by Combustion (PTE): 

PM:I 1,483 scflhr x I 7.6 1b/1.000.000 sa 

O.01lblhr x 8780 hr~ 

0.01 

x 

Iblhr 

1 IOnl2OO0 Ib 0.05 TPY i 

PM Created by Combustion (Actual); 

PM:/ 1,483 scflhr x I 7.6 1b/1.000,OOO scf 

0.01 Iblhr x 8760 hrl~ 

0.01 

x 

Iblhr 

1 tonl2OO0 Ib 0.05 TPY 
• • • • 

Oakota-3 E&P Company, LLC 


Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia Charging 2·15HC, 2·15HD 


Casing Head Gas 

[ REGULATED GREENHOUSE GAS EMISSIONSb 

C02 (PTE): 

C02 Entrained in the Produced Gas: 

Control % 

C02:! 1,483 scflhr:J x Ilf379scfnb-mole )( 129.64686 Ibllb-mole 1 x 0.86%1 x 1 98% I 1.00 IbIhr 

1.00 Iblhr :::J x 8760 hrfyr x 11 ton12oo0 IbJ 4.38 TPV] 

C02 Created by Combustion: 

c02:r---ua~----SCfiiirl x 1120,000.0 Ibtl,OOO,OOO set Cf?!:!2'b/fir! 

(-177.92 iblhi x 8760 hrfyr x 1 Ion/2000 IbJ 719.27 TPY 

Total C02 Emitted (PTE):I 783.65 TPY ] 
• • • • 

[ Dakota-3 E&P Company, LLC I 

Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charaina 2-15HC. 2·15HD 


[ Casing HeadGas- - - - --:1 


C02 (Actual): 


C02 Entrained In the Produced Gas: 


C02f 1,483-scrIi1Cl K IIlmsCfflb-mole-1 K I 29.64686 IbIlb-mole] 

wt% 

x 0.86%1 K 

Control % 

1 98% , I ­ 1.00- Iblllr 1 

C02 Created by Combustion: 

1.00 Ib/hr x 8760 hrlyr:J x IITonl2000l6 - J C 4.38IPYl 

C02:C'l;4n- SCfIilr:J x [ffO;ooo:OT6/1JjOO,OOO sa - - - 077.92 Ib/hr 

1- 177jj2 fb/hi ­ x 8760 hrlyr x CJ3on12OOOT6 d C779.27TPY -) 

Total C02 Emitted {A1lowable):C n:f.65tpy -I 

Controlled CH4 (PTE): 

CH4:' 1,483 scf/hr x '11379 scfllb-mole x 

O.A 

1 29.64686 IbIlb-mole 1 

Ib/hr x 

x 

8760 hrlyr 

wt% Control % 

25.75%' x I 98% I 

x 11 tonl2000 Ib 

O.A 

2.62 

Iblhr 

TPY 

Controlled CH4 (Actual): 

CH4:' 1,483 scf/hr x '1/379 scfllb-mole x 

_~ 

I 29.64686 IbIlb-mole I 

JIltIlr:=:J x 

x 

8760 hr~ 

wt% Control % 

25.75%1 x I 98% I 

x '1 lonl2OO0 Ib 

O.A 

2.62 

Ib/hr 

TPY 
• • • • 

Dakota-3 E&P Company, LLC 


Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia Charging 2·15HC. 2·15HD 


Casino Head Gas 

N20 Created by Combustion (PTE): 

N20:1 1.483 scflhr I x I 2.2 Ib/1.000.000 scI I = I 3.26E-03 Iblhr I 

I 3.26E-03 Iblhr x 8760 hr~ x 1 too/2ooo Ib = I 8.15E-04 TPY I I I I I I 

'C02 and N20 emission factors are from AP-42 Table 1.4·2 

(Emission Factors lor Natural Gas Combustion). 

N20 Created by Combustion (Actual): 

H20:1 1.483 scflhr I x I 2.2 Ib/1.000,OOO scI I = I 3.26E-03 Iblhr I 

I 3.26E-03 Ib/hr I x I 8760 hr~ I x I 1 ton/2OO0 Ib I = I 8.15E-04 TPY I 
• • • 

I Dakota-3 E&P Company, LLC I

• 

Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-15HC, 2-15HD 


I Heater Treater Burnera I 

Burner Rating ! 1,500,000 Btulhr !Thls burner rating reflects the combined size of all of the proposed heater treater burners at the facility. 

HOx:1 0.10 I67MMStu x 1.50 MMBtulhr ! CO:f47 -Ibltlr -! 

(o.1471lb/hr -] x 8,760 hrlyr x 11 ton 12000 Ib J '" I ,U144 -TPY -, 

co:! 0.08 I6IMMB1i.I x 1.50 MMBtulhr 1 0.124 Iblhr- -] 

[ lr.12l671i-r- -, x 8.760 hr!yr x 11 ton 12000 Ib I:: 0.541 TPY I 

S02:!5.88E..()4 IblMMBtu x 1.50 MMBtulhr! COJlO1 -Iblfir - I 

(8.82E-04 Iblhr x 8,760 hrfyr J( O]fnT2000Tb I =0.004 TPY 

PM:I 0.01·· IbIMMStu x 1.50 MMBtulhr I I-Un Iblfir . I 

( 0.0'1 167f1r - -I x 8,760 hrlyr x ! 1 ton /2000 Ib , "" 0.049 TPY -. 
• • • • 

I Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-15HC, 2-15HD 


VOC:!Q]f1-lbiMMBtO x 1.50 MMBtulhr! = 0.008 Iblhr J 

om Ib/hr J x 8.760 hrlyr x ! 1 ton 12000 Ib ! = 0.035 TPV 

I Heater Treater Burnera I 

HAP:! O~2-lb/MMBtUJ x 1.50 MMBtulhr! 0.003 Ib/hr 1 

!2Jl.!E~03 16th" x 8.760 hrlyr x [IJQi1T20lXH6] 0.012 TPY] 

C02!fll.64TlbiMMBIO x 1.50 MMBtu/hr! 176.471 Iblhr J 

[U61:+02lbihr- 1 x 8.760 hriyr x '11on 12000 Ib! 772.941 TPY­
• 
 • • • 

I - - --

I 

Oakota-3 E&P Company, LLC 

Patricia Charging 2-15H Pad 

Associated Wells: 

Patricia Charging 2-15HC. 2-15HD 

Heater Treater Burnera 

I 

'~ 

CH4:1 0.007 Ib/MMBtu 

19.92E-03 Iblhr 

H20:' 0.001 IblMMBtu 

11.98E-03 Iblhr 

)( 

)( 

)( 

)( 

1.50 MMBtulhr I 

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

1.50 MMBtulhr I 

8.760 hrlyr )( '1Ion I 2000 Ib I 

0.010 Iblhr ' 

0.043 TPY 

0.002 Iblhr 

0.009 TPY - I 

°NOx, CO, C02. & VOC Emission Factors are from AP-42 Table 1.4·1 and 1.4·2 (Emission Factors for 

Nitrogen Oxides (N20) and Methane come from Table C-l of Subpart W). 

,- -O~ -OOxTPY-, 

C -1[54- COTP'f I 

c 0.00 S02 TPV 

C 0.05 PMTPYJ 

c - 0.04 ­ VOCTPYr:::m---.:iAPTPV I 

I - 772.94 'C02 '(PV ' 

C -0:04 -CH4TPy-'1 

0:0'1 N20TPY 
• • • • 

~ .. Oakota-3 E&P Company, LLC ~ 

Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-19HCL 2-15HD 


Truck Loadout Emission Calculation II 

Saturation Vapor Molecular Temp + Load Loss 

Factor (S) Pressure (P) Weight (MW) 460 Ib/1000 gal 

12.46 I x I 0.60 I x I 2.30 I x I 42.14 I I I 510.00 I = I 1.42 

LL Truck Load Load Time Total Gas 


Ib/1,000J,tal Rate bbllhr hrs gallbbl Emissions Iblhr 


1.42 I x I 180.00 I I I 1.00 I x I 42.00 I = I 10.74 I 

LL Annual Emissions Uncontrolled 

Ib/1,000 gal bbllyr ~allbbl Ib/ton TPY C3+VOC tpv 

1.42 I x I 186784.92 I x I 42.00 I I I 2000.00 I = I 5.57 I 4.12 I 

voe 

Emissions 

Uncontrolled Control % TPY 

'--- 4.12 .J L100% J I O.~ I L~oo_1 

====== 
• • • • 

===-= 


LL Annual Emissions Uncontrolled 

Ibl1,OOO gal bbllyr aallbbl Iblton TPY HAPst~ 

1.42 I x I 186784.921 x I 42.00 I I I 2000.00 I = I 5.57 I I 0.06 

HAPs 


Emissions 


Uncontrolled Control % TPY 


0.06 I 100% 0.00 0.00 I I I I I I 

i 

LL Annual Emissions Uncontrolled 

Ibl1,OOO gal bbllyr gallbbl Iblton TPY C02tDY 

1.42 1 x I 186784.921 x I 42.00 I I I 2000.00 I =I 5.57 I 0.01 I 

CO2 


Emissions 


Uncontrolled Control % TPY 


0.01 I 1000k 0.00 0.00 1 I I I I 1

LL Annual Emissions Uncontrolled 

Ibl1,OOO gal bbllyr aallbbl Iblton TPY CH4tDY 

1.42 I x 1186784.921 x 1 42.00 1 I I 2000.00 I = I 5.57 I I 0.11 

CH4 


Emissions 


Uncontrolled Control % TPY 


0.11 I 1 100% I I 0.00 I I 0.00 I 
• • 

II Dakota-3 E&P Company, LLC I I 


II RICE Input Data I 

Combined Diesel Engines 

Hours of Operation 

Maximum HP Rating 

NOxg/hp-hr 

CO alhp..hr 

802 g/hP-hr 

PM glhp-hr 

!VOC alhp..hr 

HAP QJbh-hr 

C02g1bh-hr 

CH4 a/bh-hr 

N20 alho-hr 

• 

8760 

550 

1.49E+OO 

2.61E+OO 

4.52E-06 

4.85E-06 

1.42E-01 

1.02E-06 

2.54E-03 

2.10E-02 

4.20E-03 

• 

Description 

Englnt II ...umed to operate 8,780 hOUri per year. 

IManufacturer GUlrlntee (40 CFR 13 Subpart IDlrequll'llllentl), ... Altachment F 

.....uflcturtr Guerlntee (40 CFR 13 Subpart IRlrequll'llllentl), ...Attachment F 

"P-42 Table 3.3-1 

AI42Table 3.3-1 

Manuflcturer GUlllntee {40 CFR 13 Subpart 1m requllll'llllltll, ...Atblchment F 

1AP-42 Table 3.3-1 

1AP-42 Table 3.3-1 

140 CFR98 Sub.,art C, Table Co2 

140 CFR 98 Sub.,art C, Table Co2 

Recycle Pump Description 

Hours of Operation 8760 Englnt lIa..umld to operate 8,780 hOUri per y... 

Maximum HP Ratina 16 IManuflcturer'l mulmum hp rating. 

NOx Q/hp..hr 4.99E+00 1AP-42 Table 3.3-1 

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

802 a/ho-hr 2.68E-01 1AP-42 Table 3.3-1 

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

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

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

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

CH4 alho-hr 2.10E-02 40 CFR 98 Subpart C, Table Co2 

N20 alho-hr 4.20E-03 40 CFR 98 Subpart C, Table C.z 
• • • • 

ENGINE #1 

[ 55f:J MAX HP 

!i2Ii. 1.49E+OO Ii!!:!P-HRI x 550 HP x 11 Ib 1453.6 ~rams 1.81E+OO Iblhr I x 8160 hr!t! x (1 ton 12000]lil =P .93E+OONOx !PiC] 

~ 2.61E+OO Ii!!:!P-HRI x 550 HP x 11 Ib I 453.6 I.!rams 3.11E+OO Iblhr I x 8160 hr!t! x 11 ton 12000lbl I 1.39E+01 CO TPY 

802: 4.52E-06 I!!HP-HRI x 550 HP x 11 Ib 1453.6I!rams 5.48E..08 Iblhr x 8160 hr~ x 1 ton I 2000lbI 2.40E-05 502 TPY 

PM: 4.85E-06 I!!!:!p-HRI x 550 HP x 11Ib/453.6I!rams 5.88E..08 Iblhr x 8160 hr!t! x 1 ton I 2000lbI 2.58E-05 PM TPY 

VOC: 1.42E-01 li!!:!p-HRI x 550 HP x 11 Ibl 453.6 srams 1.12E-01 Iblhr x 6160 hr!t! x 1 ton 12000lbl 7.53E-01 voc TPY 

HAP; 1.02E-06 Ii!!:!P-HRI x 550 HP x 11 Ib 1453.6srams 1.24E..08 Iblhr x 8160 hr!t! x 1 ton 12000lb I 5.42E-06 HCHO TPY 

~ 2.54E-03 S/HP-HRI x 550 IHP x 11 Ib 1453.6 ~rams 3.01E-03 Iblhr x 6160 hr!t! x 1 ton 12000lb I 1.35E-02 CO2 

CH4: 2.10E-02 I!!!:!p-HRI x 550 HP x 11 Ib 1453.6 ~rams 2.55E-02 Iblhr x 8760 hr!t! x 1 ton 12000lb I 1.12E-01 CH4 

~ 4.~E-C)l glHP-I-iRI x 550 HP x 11 Ib 1453.6 grams = 5.09E-03 Iblhr x I 8760_ hrlyr x 1 ton 12000lbI 2.23E-02 N20 

Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Cha!9l!!9.2-15HC, 2-15HD 


C Reciprocating Engine Emissions -_. - -- - _.. - - - I 
• • • 

[ Oakota-3 E&P Company, LLC 


Patricia Charging 2·15H Pad 


Associated Wells: 


Patricia Charging 2·15HC, 2·15HD 


Reciprocating Engine Emissions -~ 

ENGINE #2 

16 IMAXHP 

NOx: I 4.99E+OO gIHP-HR! x 16 HP x 11 Ib 1453.6 srams I x 0.18 fb/hr x 8760 hr/;t! x 1 ton I 2000fb I = 7.71E-Ol NOxTPY] 

!<2;. I 3.16E+00 gIHP-HR I x 16 HP x 11 fb 1453.6 §!rams I x 0.11 fblhr x 8760 hr!;t! x 1 ton I 2000fbI 4.88E·01 COTPY 

§.Q1;, I 2.88E-01 g/HP-HR! x 16 HP x 11 fb 1453.6 Ilrams I 9.46E-03 fblhr x 8760 hr!;t! x 1 ton I 2000lbI 4.14E-02 502 TPY 

eM.;. I 3.27E-01 g/HP-HR! x 16 HP x 11 fb I 453.6 IIrams I 1.15E-02 fb/hr x 8760 hr!;t! x 1 ton I 2000fb I 5.05E-02 PM TPY 

I 9:&OE+OO- 91HP-HR] x 16 HP x 11 fb 1453.6 Ilrams x 0.35 fblhr x 8760 hr!;t! x 1 ton 12000lbl 1.51E+OO VOC TPY 

.!:!!e;. I 2.2OE.:o1 gIHP.HR! x 16 HP x 11 Ib I 453.6I1rams 0.01 Iblhr x 8760 hr!;t! x 1 ton 12000fbI 3.40E·02 HAP TPY 

I '(90E+02 Q/HF>:f"m x 16 HP x 11 lb I 453.6I1rams 1.73E+01 lblhr x 8760 hr!;t! x 1 ton 12000lbI 7.57E+Ol C02 TPV 

CH4: I 2.10E-02 gIHP-HRI x 16 HP x 11 fb I 453.6 §!rams 7.41E-04 Iblhr x 8760 hr!;t! x 1 ton I 2000lbI 3.24E-03 CH4 TPY 

N20: I UOE-03 g/HP.HR! x 16 HP x Ii Ib I 453.6 grams 1.48E-04 Iblhr x 87~ j1r/yl' x 1 ton I 2000fb I 6.49E·04 N2Q TPiJ 

• 

• • • • 


Oakota-3 E&P Company, LLC 


Patricia Charging 2-15H Pad 


Associated Wells: 


Patricia Charging 2-15HC, 2-15HD 


Reciprocating Engine Emissions 

TOTALS 

[!]OE+ilONOiTPY--- :J 

1.44E+01 CO TPY 

4.14E"()2 S02 TPV 

5.08E"()2 PM TPY 

2.27E+OO VOC TPY 

3.40E"()2 HAP TPY 

7.57E+01 C02 TPY 

1.15E..()1 CH4 TPY 

2.30E"()2 H20 TPY 
• 


ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS 

• E&P Tanks Emission Summary 

• E&P Tanks Linear Relationship (Emission Factor) 

• 

• 

Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
Mandaree Field 1000 BOPD wt% 

****************************************************************************************** * project Setup Information * 

****************************************************************************************** 

project File : y:\projects\wil1iams Exploration & Production WEP\WEP211324 Ft. Berthold 

IR well work\E&p Tanks\Mandaree Field 1000 BOPD.ept Flowsheet Selection oil Tank with Separator calculation Method RVP Distillation 

Control Efficiency 100.0% 

Known Separator Stream Low Pressure oil 

Entering Air Composition No 

Filed Name Mandaree 


well Name Cross 2-13H and patricia charging 4-15H Averages
 Permit Number Dakota-3 E&P Company, LLC 

Date 9/24/2010 

• 

****************************************************************************************** 

* Data Input * 

****************************************************************************************** 

separator pressure 51.00[ps; g] sep~rator Temperature 82.50[F] Amblent Pressure 14.70[ps;a] Ambient Temperature 70.00[F] c10+ SG 0.8000 

CI0+ MW 235.14 

LOW Pressure oil ---------------------------------------------------------------------­ NO. component wt % 

1 H2S 0.0014 

2 02 0.0000 

3 C02 0.0042 

4 N2 0.0015 

5 c1 0.0320 

6 c2 0.3654 

7 c3 1.2089 

8 ;-C4 0.3443 

9 n-C4 1. 5191 

10 ;-c5 0.6508 

11 n-C5 1. 2185 

12 c6 1. 3933 

13 c7 6.7524 

14 C8 15.9338 

15 c9 14.3170 

16 C10+ 53.7971 

17 Benzene 0.0479 

18 Toluene 0.0997 

19 E-Benzene 0.0600 

20 xy1enes 0.3998 

21 n-C6 1.4864 

22 224Trimethy1p 0.3663 

• sales oil ----------------------------------------------------------------------------­ production Rate 1000[bb1/day] Days of Annual operation 365 (days/year] API Gravity 41.85 

Reid vapor Pressure 5.90[ps;a] 

****************************************************************************************** 

* calculation Results * 

****************************************************************************************** 

-- Emission Summary ---------------------------------------------------------------------­ Item Uncontrolled Uncontrolled 

[ton/yr] [lb/hr] 

page 1---------------------------------------------------------------- E&P TANK 

Total HAPs 8.550 1.952 

Total HC 812.744 185.558 

vocs, C2+ 796.480 181.845 

VOCs, c3+ 612.595 139.862 

page 1 

• 

• 

Mandaree Field 1000 BOPD wt% 

uncontrolled Recovery Info. 

vapor 40.2300 [MSCFD] 

HC vapor 40.0300 [MSCFD] 

GOR 40.23 [sCF/bbl] 

Emission composition -----------------------------------------------------------------­ No component uncontrolled uncontrolled 

[ton/yr] [lb/hr] 

1 H2S 0.689 0.157 

2 02 0.000 0.000 

3 co2 2.160 0.493 

4 N2 0.786 0.179 

5 cl 16.264 3.713 

6 C2 183.886 41.983 

7 c3 375.375 85.702 

8 i-C4 37.149 8.482 

9 n-C4 112.787 25.750 

10 i-C5 17.863 4.078 

11 n-C5 24.862 5.676 

12 c6 8.648 1.974 

13 c7 13.803 3.151 

14 C8 10.281 2.347 • 

15 c9 3.270 0.747 

16 C10+ 0.004 0.001 

17 Benzene 0.234 0.053 

18 Toluene 0.136 0.031 

19 E-Benzene 0.027 0.006 

20 xylenes 0.156 0.036 

21 n-C6 7.394 1.688 

22 224Trimethylp 0.604 0.138 

Total 816.378 186.388 

-- Stream Data --------------------------------------------------------------------------­ NO. component MW LP oil Flash oil sale Oil Flash Gas W&S Gas Total Emissions ~% ~% ~% ~% ~% ~% 

1 H2S 34.80 0.0014 0.0010 0.0000 0.0873 0.0856 0.0861 

2 02 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 


3 C02 44.01 0.0042 0.0020 0.0000 0.4818 0.1765 0.2642 


4 N2 28.01 0.0015 0.0001 0.0000 0.3044 0.0123 0.0962 


5 cl 16.04 0.0320 0.0079 0.0000 5.2226 0.6866 1.9891 


6 C2 30.07 0.3654 0.2356 0.0039 28.3624 20.1288 22.4930 


7 c3 44.10 1.2089 1.0468 0.4786 36.1613 49.8497 45.9192 


8 i-C4 58.12 0.3443 0.3257 0.2757 4.3503 4.6218 4.5438 


9 n-C4 58.12 1.5191 1.4623 1.3185 13.7647 13.8076 13.7953 


10 i-c5 72 .15 0.6508 0.6432 0.6257 2.2771 2.1480 2.1850 


11 n-C5 72.15 1.2185 1.2094 1.1888 3.1795 2.9854 3.0410 


12 c6 86.16 1.3933 1.3945 1.3984 1.1369 1.0640 1.0850 


13 c7 100.20 6.7524 6.7753 6.8342 1.8207 1.7133 1.7442 


14 C8 114.23 15.9338 16.0015 16.1730 1.3430 1.2744 1.2941 


15 c9 128.28 14.3170 14.3815 14.5440 0.4133 0.4189 0.4174 


16 CI0+ 235.14 53.7971 54.0465 54.6758 0.0006 0.0005 0.0006 


17 Benzene 78.11 0.0479 0.0480 0.0483 0.0298 0.0281 0.0285 


18 Toluene 92.13 0.0997 0.1001 0.1011 0.0174 0.0165 0.0166 


19 E-Benzene 106.17 0.0600 0.0603 0.0610 0.0035 0.0032 0.0033 


20 

21 xylenes n-c6 

106.17 

86.18 1.4864 

0.3998 0.4016 

1.4889 1.4959 

0.4059 0.0196 

0.9466 

0.0187 

0.8874 

0.0191 


0.9045 


•

22 224Trimethylp 114.24 0.3663 0.3677 0.3711 0.0772 0.0726 0.0739 


MW 143.08 144.90 148.98 39.02 43.55 42.14 


Stream Mole Ratio 1.0000 0.9829 0.9448 0.0171 0.0381 0.0552 


Heating value [BTU/SCF] 2225.52 2481.29 2401. 97 


Gas Gravity [Gas/Air] 1. 35 1. SO 1.45 


Bubble Pt. @ 100F [psia] 32.28 20.39 7.37 


page 2---------------------------------------------------------------- E&P TANK 

RVP @ 100F [psia] 15.35 12.04 6.01 


spec. Gravity @100F 0.677 0.678 0.680 


Page 2 

• 
Oil 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 Mandaree Field Dakota-3 Wells 

Separator: 51 psig, 83 degF 

Flash Valve: 13.7 psia, 50 degF 

Sales Oil: API Gravity 41.9, Reid Vapor Pressure 5.90 pSia, 365 days/year 

• 

Outputs: 

Oil Production Rates (bbVday) (P) 0 50 100 300 1000 

Emission (tonslyr) 

Total HC 0 40.6372 81.2744 243.8232 812.744 

VOCs, C3+ 0 30.62975 61.2595 183.7785 612.595 

Total HAPs 0 0.4275 0.855 2.565 8.55 

VOC (C3+) Emission Factor: 0.6126 tpy/BOPD 

HAP Emission Factor: 0.00855 tpy/BOPD 

Tank Emissions by Production Rate 

-+-Tolal HAPs 

_VOCs,C3+ 

-linear (Tolal HAPs) 

-linear (VOCs, C3+} 

bbl/day 

• 

700 

600 

... 500 

I 400 

300 

0 200 - 100 

0 

0 500 1000 1500 

• 

• 

ATTACHMENT D: REPRESENTATIVE LOW PRESSURE OIL 

ANALYTICAL DATA 

I


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


Labul'atOJl • Gas Measurement 

Emissions Testing • Sample Collect Ion 

A2lA Aa:n:dited • NElAf' Au:n:dUed • ErA CertlOed 

29 Country Acr~ Rd. Riverton. \lOy 82.501 • Toll F..,e: (866) 98!.-0866 • E-.....II: Inlow I',,,dslon-Labs,c:om • Online, W'WW.I',ec:lslon-Labs.com 

EXTENDED HYDROCARBON (GLYCALC) UQUID STUDY 

Company .................... ZENERGY 


Lab Number ................ CR-10330 Study Number .......... CR-2 


Date Sampled .............. 7-15-2010 Date Tested ............. 7-23-2010 


• 

Sample Identification .................... CROSS 2-13 H CRUDE Oil 

Sample Location .......... MONTANA. 


Sample Pressure ......... 22 PSIG Sample Temperature .... 95 F 


Type Sample ............... SPOT County ...................... DUNN 


Test method ................ GPA-2286 Sampling Method........ YZ PISTON 


Components Mole % Weight % Liq. Vol. % 

• 


Hydrogen Sulfide .......... 0.003 0.001 0.001 


Oxygen ...................... 0.000 0.000 0.000 


Carbon Dioxide ............ 0.013 0.004· 0.004 


Nitrogen ..................... 0.007 0.001 0.001 


Methane ..................... 0.180 0.021 0.050 


Ethane ....................... 1.602 0.342 0.709 


Propane ..................... 4.036 1.264 1.839 


iso-Butane .................. 0.855 0.353 0.463 


n-Butane .................... 3.974 1.640 2.072 


iso-Pentane ................ 1.378 0.706 0.833 


n-Pentane ................... 2.569 1.316 1.540 


Hexanes ..................... 2.510 1.536 1.707 


Heptanes .................... 10.694 7.610 8.159 


Octanes ..................... 19.351 15.699 16.394 


Nonanes ..................... 17.072 15.551 15.886 


Decanes+ ................... 31.435 51.099 47.376 


Benzene ...................... 0.093 0.052 0.043 


Toluene ....................... 0.166 0.109 0.092 


Ethylbenzene ............... 0.104 0.078 0.066 


Xylenes ....................... 0.618 0.466 0.397 


n-Hexane .................... 2.798 1.712 1.903 


2,2,4-Trimethylpentane... 0.542 0.440 0.466 


TOTALS ..................... 100.000 100.000 100.000 


• 

• 

ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

2-Methylpentane 1.486 0.910 1.011 

3-Methylpentane 1.024 0.627 0.696 

n-Hexane 2.798 1.712 1.903 

2.2,4-Trimethylpentane 0.542 0.440 0.466 

Benzene 0.093 0.052 0.043 

Toluene 0.166 0.109 0.092 

Ethylbenzene 0.104 0.078 0.066 

m-Xylene 0.066 0.050 0.042 

p-Xylene 0.436 0.329 0.280 

o-Xylene 0.116 0.087 0.074 

API GRAVITY AT 60/60 F, calculated ........................................................................ 


SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 


RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 


AVERAGE MOLECULAR WEIGHT .......................................................................... 


AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 


TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated ................................................ 


AVERAGE BOILING POINT, F, ................................................................................ 


CUBIC FEET OF GAS I GALLON OF LIQUID, as Ideal Gas .......................................... 


BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 


LBS I GALLON OF LIQUID, calculated ...................................................................... 


,,' "} HI< I'. \l.[ ( '\U I I\TI\;',:· Pl.RIOR\H-D tSI'.(. PHY:;l( \1 (( l",,,T /I'-.T' fR( )\1 "P'I ,14', (Ill IHI L\lll I" 

01 PII),,!( -\1 ( (,:,~n',T'> J( IR HY[)R( )(-\R!l( I"S -,,,I) ('THI,R ( (·;.lpotl"[1' OJ I'.TI',RESl 

• 

60.3 


0.7378 


0.7958 


140.803 

228.881 

33.400 

299.063 

19.106 

122456.887 

6.152 

• 

• 
- -------------

• 


EXTENDED HYDROCARBON LIQUID STUDIES 

( FRTIII(\TF ()J" \~ \1 Y:-;I:-­

Company................ PRECISION ANALYSIS 


Lab Number............. CR-10330 Study Number............ CR-2B 


Date Sampled ............. 7-15-2010 
 Date Tested .............. 7-22-2010 


Sample Identification ..•..........••. ZENERGY - CROSS 2·13 H CRUDE OIL 


• 

Sample Location ......... MONTANA. 

Sample Pressure .......... N/A Sample Temperature ..•• N/A 

Flowrate ....•....•...•••.•. N/A County..................... DUNN 

1-QUART 

Test Method.............. VARIOUS Sample Container ........ BOTTLE 


TEST PERFORMED RESULTS 


API GRAVITY AT 60/60 F (ASTM D-287), observed ...................... 42.5 


SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated .......... 0.8132 


REID VAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 5.2 PSIG 


TOTAL SULFUR CONTENT (ASTM D-5453), PPMW .................. 658.98 PPMW 


TRUE VAPOR PRESSURE (ASTM D-2889), PSIA AT 100 F ........... N/A 


BASIC SEDIMENT AND WATER CONTENT, % BY VOLUME.... N/A 


COPPER STRIP CORROSION (ASTM D-130), 1 HOUR AT 100 F........... N/A 


FREE WATEa, observed........................................................ . N/A 


• NOTATIO:S; ".u TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOG\ 

Ol'TLINED BY rHE AMERICAN SOCIETI FOR rESTING AND MATERIALS (ASTM) 

• 

•
 l.4Ioo,alorJ Ga! l'Ie...,."re.."l>U,1 

[minto... luling > 5a"'p.I~ CoII""lk", 

Chromatogram Cross 2 -I3H C :\GCsolution\DRO\DRO Data\08-2010\08-0 \-20 1 O\Cross 2- I3 H.gcd - Channel \ 

50000 100000 \ 200000 250000 

~··~~~~~'---------·----·~--2.6671 

bL-­__ 3.6321 

----·------··-----~·--·4.0691 

====-U(.l8..J:__________ 5.6081 Decane (CIO) 

------­ 5.947 1 

:r.:'::'c--~-~·~----------7.0831 

c=~-------------9.7241 

~,.;;...-------- 10.9111 

--------12.0311 

-----­ 13.0881 

__fr+---- 14.089! 

15.947 ! G-'erphenyl 

Intensity 

• 

• 

:5' 

• 

3 
• 

PREIPISIQ._ Laboratory • Ga~Mea!;urcmcnt

Emissions Testing • Sample Collection 

WfJ1,ttASi§·f1tt\a:IAt\i;l2§i§.lifflaAUitUhffll 

~~AN~_........ 


29 c.ountry Acres Rd, RI~"rton, "" alSOI • Toll Fn:..' 866 

' ( ) 98~-0866 • E·...all: Infoii' "r"clslon·Labs.com • Onll..-' ~. b "_1 La~' ...... ---~ ... "C_ ou" .,.,.,.(;0ftI 

EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY 

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 

Region 8 Air Program 

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY iEPA 

Check List - Application for New Construction 

(FonnNEW) 

Please check all that apply to show how you are using this form 

• Proposed Construction of a New Facility 

o Proposed Construction of New Equipment at an Existing Facility 

o Proposed Modification of an Existing Facility 

o Other - Please Explain 

Use ofthis information request form is voluntary and not yet approved by the Office of Management and Budget 

The following is a check list ofthe type of information that Region 8 will use to process information on your proposed 

project. While submittal ofthis form is not required, it does offer details on the information we will use to complete your 

requested approval and providing the information requested may help expedite the process. Use ofapplication forms for 

this program is currently under Office ofManagement and Budget review and these information request forms will be 

replaced/updated after that review is completed. 

Please submit information to 

following two entities: 

The Tribal Environmental Contact for the specific reservation: 

Minor NSR Permitting Coordinator 

U.S. EPA, Region 8 Ifyou need assistance in identifying the appropriate Tribal 

1595 Wynkoop Avenue, 8P-AR Environmental Contact and address, please contact the EPA 

Denver, CO 80202·1129 Region 8 Tribal Air Coordinator: 

Alexis North, EPA Region 8 Tribal Air Coordinator 

303-312-7005 

north.alexis@epa.gov 

A. GENERAL FACILITY INFORMATION 


1. (a) Company Name 

Dakota-3 E&P Company, LLC 

(b) Operator Name 

Dakota-3 E&P Company, LLC 

2. Facility Name 

Patricia Charging 2-15H Pad 

3. Type ofOperation 

Oil and Gas Production 

6. NAICS Code 

4. Portable Source? o Yes 

5. Temporary Source? o Yes 

7. SIC Code 

I2i;1 No 

I2i;1 No 
• 

ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

2-Methylpentane 1.272 0.734 0.826 

3-Methylpentane 0.908 0.524 0.590 

n-Hexane 2.204 1.271 1.431 

2,2,4-Trimethylpenta ne 0.387 0.296 0.317 

Benzene 0.085 0.044 0.038 

Toluene 0.148 0.091 0.078 

Ethylbenzene 0.060 0.043 0.037 

m-Xylene 0.058 0.041 0.036 

p-Xylene 0.298 0.212 0.183 

o-Xylene 0.117 0.083 0.072 

API GRAVITY AT 60/60 F, calculated........................................................................ 


SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 


RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 


AVERAGE MOLECULAR WEIGHT .......................................................................... 


AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 


TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated ................................................ 


AVERAGE BOILING POINT, F ................................................................................. 


CUBIC FEET OF GAS I GALLON OF LIQUID, as Ideal Gas .......................................... 


BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 


LBS I GALLON OF LIQUID, calculated ...................................................................... 


rill I \BII-­

(,I !'IIY~/( \1 ( \';q r~ 1< 'R HYDR( \( -\RB( J"~ -\'D (lTHU{ ( ( )\11'( 't '-I), ( ,[ 1"- 11- RFS! 

n, !III" ITI R-\I (,\, I'DldR'l 

57.8 

0.7475 

0.8050 

149.417 

241.399 

46.319 

314.836 

18.857 

122700.693 

6.232 
• 


EXTENDED HYDROCARBON LIQUID STUDIES 


Company........••...... ZENERGY 


Lab Number.•....•.....• CR-10330 Study Number.•••....•... CR-3B 

Date Sampled .•...•....••. 7-15-2010 Date Tested••.•.••..•.•.. 7-22-2010 

Sample Identification ...•...••.•..•.. PATRICIA CHARGING 4-15 H CR1JDE OIl 

• 

Sample Location .•..••.•. MONTANA. 

Sample Pressure .......... N/A Sample Temperature.... N/A 

FIowrate................... N/A County..................... DUNN 

I-QUART 

Test Method.............. VARlOUS Sample Container ........ BOTfLE 


TEST PERFORMED RESULTS 

API GRAVITY AT 60/60 F (ASTM D-287), observed ...................... 41.2 


SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated .......... 0.8193 


REID VAPOR PRESSURE (ASTM D-323), PSIGAT 100 F.............. 6.6 PSIG 


TOTAL SULFUR CONTENT (ASTM D-5453), PPMW .................. 940.25 PPMW 


TRUE VAPOR PRESSURE (ASTM D-2889), PSIA AT 100 F ........... N/A 


BASIC SEDIMENT AND WATER CONTENT, % BY VOLUME.... N/A 


COPPER STRIP CORROSION (ASTM D-130), 1 HOUR AT 100 F........... N/A 


FREE WATER, observed ......................................................... N/A 


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

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

• 

I.A;D-..)'-"'iOf) {.Ja~ ft'lta5..n{rY,ini 

[ ..."'ohm, '.."lIng , S;in.plt CnU.,OIOIi 

_ildMiftffE&iULiJii&,I!f't°';'ffimw. • 

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

o 50000 100000 150000 200000 250000 

Intensity 

~.~.~.~_--,;;;;..c;..:-.___ ________- ____. 2.6671 

.;)!w"-__ 3.6351 

~~-------,.---------.- 4.0701 

====..5.5.lll.L_________._5.6101 Decane (CIO) 

-~-~---------- 7.0841 

• ~===8.634!--··---·---..- 8.4531 


~~----------- 9,7251 


~------- 10.913/ 


-------- 12.0311 


----- 13,0881 


--til_<+-- 14,0911 


15.9501 'HeIphenyl 

• 

:;' 

• 

3 
ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS 


I

• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• • • • 

A' M d A G C . I Data (Coli , d 10/11/2011), ... 
 ....1­ """'.o... e 

COl 

IWI") 

44.010 

Nit"",... 

IWt%) 

28.013 

HZS 

IM_, 

34.081 

Cl 

1Wt%, 

16.043 

a 

IWt%, 

30.069 

a 

IWI", 

44.096 

14:4 

1Wt%, 

58.122 

"4:4 

1Wt%) 

58.122 

14:5 

1Wt%1 

72.149 

n.cs 

1Wt%) 

72.149 

(6 

IWt%I 

86.180 

C1 

1Wt%, 

101.21 

CI+ 

1Wt%1 

114.23 

1Wt%, 

18.112 

ToIue... 

IWt%) 

92.140 

E_..... 

IWt%I 

106.110 

leyl..... 

IWt%1 

106.160 

n·.....". 

IWt%I 

86.180 

...-thy! 

pent.... 

114.230 

........ V.h,. 

IlItu/seII 

.pe.Iff< 

Gravity 

c..lculat4ld 

""I. 

MotHuiat 

Weicht 

Alishill Fa.lS-9 1.161 3.626 0 36.543 24.689 18.ll7 1.949 5.713 1.092 1.159 1.621 1.321 0.545 0.251 0.264 0.014 0.462 0.657 0.004 1462.236 0.8862 25.666 I 

\11101121-34 0.836 2.541 0 33.17 23.484 18.569 2.543 7.523 2.219 3.884 2.219 1.481 0.166 0.085 0.11 0.006 0.026 1.138 0 1558.1 0.9345 27.065 I 

e••rs Tail 32-29 0.724 1.414 0 20.353 26.461 28.74 3.763 10.995 1.776 2.491 1.158 0.773 0.498 0.038 0.216 0.014 0.05 0.536 0 1796.8 1.0738 31.101 

at2·1 0.81 1.352 0 19.208 2L796 27.321 4.559 14.169 2.623 3.749 1.845 1.209 0.121 0.D75 0.097 0.007 0.021 0.975 0.002 1874.11 1.1253 32.591 

Skunk Creek 1·23 0.693 3.545 0 25.407 22.578 25.451 3.399 11.195 2.037 2.674 0.515 0.769 0.487 0.04 0.ll7 0.016 0.066 0.771 0 1663.5 1.0141 29.37 

Nathan H.le 3·18 0.873 3.471 0 32.094 16.795 17.765 3.156 11.786 2.666 3.871 2.76 2.453 0.109 0.53 0.215 0.01 0.038 1.405 0.002 1602.8 0.9765 28.281 

High H.wk 4-9 0.681 0.471 0 13.456 30.949 33.204 3.787 11.001 1.714 2.273 0.941 0.252 0.605 0.043 0.19 0.011 0.049 0.375 0 1945.1 1.1551 33.454 

Average'! I 0.1163 I 2.346 I 0.000 I 25.141 I l3.an I 24.195 I 3.308 I 10.340 I 2.018 I 2.951 I 1.581. I 1.183 1 O.3!2 LJI·IS!, 1~17U 0.011 0.101 0.837 0.001 1100.387 1.02' 29.64686 

Note: An calculations were preformed by Precision Anatvsis using physkal constants from GPA~2145-09, 
• 

29 Count'}' ACflts Rd, Riverton, WY 82501 

Onlln., _.Preclalon·Labs.com 

E-mall.ln.o(!iPreclalon·Labs.com 

Toll Fre. Numbe.. (866) 985..0866 

Client: BISON ENGINEERING 

Sample 10: AliSIA FOX 16-9 

Unique#: 

Sample Temperature: 62 DEG F 

Sampled By: TC 

County: DUNN 

Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


10/11/2011 

10/11/2011 

20 PSI 

•

ONLINE 

Components Mole % Weight % Liq. Vol. % 


Carbon Dioxide ............. 0.677 1.161 0.551 


Hydrogen Sulfide ........... 0.000 0.000 0.000 


Nitrogen ...................... 3.323 3.626 1.742 


Methane ...................... 58.464 36.543 47.240 


Ethane ........................ 21.074 24.689 26.862 


Propane ....................... 10.662 18.317 13.999 


iso-Butane ................... 0.861 1.949 1.342 


n-Butane ...................... 2.523 5.713 3.791 


iso-Pentane .................. 0.389 1.092 0.677 


n-Pentane .................... 0.599 1.684 1.035 


Cyclopentane ............... 0.028 0.075 0.039 


n-Hexane ..................... 0.196 0.657 0.384 


Cyclohexane ................ 0.196 0.642 0.317 


Other Hexanes ............. 0.147 0.492 0.287 


Heptanes ..................... 0.338 1.321 0.744 
 • 

Methylcyclohexane ........ 0.129 0.493 0.247 


2,2,4-Trimethylpentane... 0.001 0.004 0.002 


Benzene ...................... 0.085 0.257 0.113 


Toluene ....................... 0.073 0.264 0.117 


Ethylbenzene ............... 0.003 0.014 0.006 


Xylenes ....................... 0.112 0.462 0.206 


C8+ Heavies ................ 0.122 0.545 0.299 


Totals ........................ 100.000 100.000 100.000 


• 
• 


ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

Cyclopentane 0.028 0.075 0.039 

Cyclohexane 0.196 0.642 0.317 

• 

2-Methylpentane 0.092 0.310 0.181 

3-Methylpentane 0.054 0.182 0.106 

n-Hexane 0.196 0.657 0.384 

Methylcyclohexane 0.129 0.493 0.247 

2.2,4-Tlimethylpentane 0.001 0.004 0.002 

Benzene 0.085 0.257 0.113 

Toluene 0.073 0.264 0.117 

Ethylbenzene 0.003 0.014 0.006 

m-Xylene 0.018 0.073 0.033 

p-Xylene 0.076 0.313 0.139 

o-Xylene 0.018 0.076 0.034 

SPECIFIC GRAVIlY @ 60/60 F, calculated ................................................... 0.8862 


TOTAL GPM (Ethane Inclusive) ................•••.........•....•................•............•. 10,561 


CALCULATED BTU 1 REAL CF @ 14.73 PSIA, dry basis.................................. 1462,236 


CALCULATED BTU 1 REAL CF@ 14.73 PSIA, wet basis .................................. 1437.527 


AVERAGE MOLECULAR WEIGHT............................................................ 25.666 


MOLAR MASS RATIO.............................................................................. 0.8862 


RELATIVE DENSIlY ( G" Z (Air) 1Z ), calculated ........................................ 0.8911 


IDEAL GROSS HEATING VALUE, BTU 1 IDEAL CF @ 14.696 PSIA .................. 1450.907 


COMPRESSIBIUlY FACTOR (Z) .............................................................. 0.99453 


PROPANE GPM ..................................................................................... 2.9297 


BUTANEGPM ...................................................................................... . 1.0743 


GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 0.9357 


lHI I ,iii I ' 

ill PHY'H \1 « )" 1 .\ "'T' I·' )H HYJ)IH )t ;](W ~"lJ ' q III F ( , '\11" ,! "I), (" I" IT HI 'I

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

• 

• 

29 Country Acrl.'s Rd, Riverton, WY 82501 PRECISION7 Online, www.Precls\on-L1obs.com

s 

Client: BISON ENGINEERING 

Sample 10: HIGH HAWK 4-9 

Unique #: 

Sample Temperature: 59 DEG F 

Sampled By: TC 

County: DUNN 

E ....... i1: Inf~r.clsion·L1obs.com 

Toll Fre", Number. 1866) 985-0866 


Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


10/11/2011 

10/11/2011 

25 PSI 

•

ONLINE 

Components Mole % Weight % Liq. Vol. % 


Carbon Dioxide ............. 0.517 0.681 0.356 


Hydrogen Sulfide ........... 0.000 0.000 0.000 


Nitrogen ...................... 0.562 0.471 0.249 


Methane ...................... 28.060 13.456 19.176 


Ethane ........................ 34.433 30.949 37.122 


Propane ....................... 25.191 33.204 27.977 


iso-Butane ................... 2.180 3.787 2.875 


n-Butane ...................... 6.332 11.001 8.047 


iso-Pentane .................. 0.795 1.714 1.172 


n-Pentane .................... 1.017 2.194 1.487 


Cydopentane ............... 0.037 0.079 0.045 


n·Hexane ..................... 0.146 0.375 0.242 


Cyclohexane ................ 0.047 0.119 0.065 


Other Hexanes ............. 0.291 0.749 0.482 


Heptanes ..................... 0.084 0.252 0.157 


•

Methylcyclohexane ........ 0.025 0.073 0.040 


2,2,4-Trimethylpentane ... 0.000 0.000 0.000 


Benzene ...................... 0.Q18 0.043 0.021 


Toluene ....................... 0.069 0.190 0.093 


Ethylbenzene ............... 0.004 0.011 0.005 


Xylenes ....................... Om5 0.049 0.024 


C8+ Heavies ................ 0.177 0.605 0.366 


Totals ........................ 100.000 100.000 100.000 


• 
• 

ADDITIONAL BETX DATA 


Components Mole % 
 Weili,ht % Li~. Vol. % 

• 

Cydopentane 0.037 0.079 0.045 

Cyclohexane 0.047 0.119 0.065 

2-Methylpentane 0.183 0.471 0.303 

3-Methylpentane 0.108 0.278 0.179 

n-Hexane 0.146 0.375 0.242 

Methylcyclohexane 0.025 0.073 0.040 

2.2,4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.018 0.043 0.021 

Toluene 0.069 0.190 0.093 

Elhylbenzene 0.004 0.011 0.005 

m-Xylene 0.002 0.008 0.004 

p-Xylene 0.010 0.033 0.016 

o-Xylene 0.003 0.008 0.004 

SPECIFIC GRAVlTY @ 60/60 F, calculated................................................... 1.1551 


TOTAL GPM (Ethane Inclusive) ................................................................. 19.847 


CALCULATED BTU / REAL CF @ 14.73 PSIA. dry basis .................................. 1945.085 


CALCULATED BTU / REAL CF @ 14.73 PSIA. wet basis .................................. 1911.926 


AVERAGE MOLECULAR WEIGHT........................................................... . 33.454 


MOLAR MASS RATIO.............................................................................. 1.1551 


RELATIVE DENSITY ( G x Z (Air) / Z ), calculated........................................ 1.1668 


IDEAL GROSS HEATING VALUE, BTU / IDEAL CF @ 14.696 PSIA.................. 1921.067 


COMPRESSIBIliTY FACTOR (Z).............................................................. 0.98992 


PROPANE GPM ................................................................................... .. 6.9222 


BUTANEGPM ....................................................................................... 2.7025 


GASOliNE GPM (PENTANE AND HEAVlER) ........................................... 1.0377 


• 

• 

• 

PRECISION;? 
 ~SIS 

Client: BISON ENGINEERING 

WILLIAMS 

Sample 10: NATHAN HALE 3-18 

Unique#: 

Sample Temperature: 59 DEG F 

Sampled By: TC 

County: DUNN 

29 Country Acres Rd, Riverton. WY 82501 

Online: _w.Prec:I.,on·....b ••com 

E·mall! In~Pr..cl.lon·....bs.com 

Toll Free Numberl 1866) 985.(1866 

Analysis Date: 10/11/2011 

Date Sampled: 10/11/2011 

Purpose: 

Sample Pressure: 15 PSI 


•

Type Sample: ONLINE 


Coml:0nents Mole % We!iht % Liq. Vol. % 


Carbon Dioxide ............. 0.561 0.873 0.443 


Hydrogen Sulfide ........... 0.000 0.000 0.000 


Nitrogen ...................... 3.504 3.471 1.784 


Methane ...................... 56.578 32.094 44.375 


Ethane ........................ 15.797 16.795 19.545 


Propane ....................... 11.394 17.765 14.522 


iso-Butane ................... 1.536 3.156 2.325 


n-Butane ...................... 5.735 11.786 8.364 


iso-Pentane .................. 1.045 2.666 1.768 


n-Pentane .................... 1.419 3.619 2.379 


Cyclopentane ............... 0.102 0.252 0.139 


n-Hexane ..................... 0.461 1.405 0.877 


Cyclohexane ................ 0.304 0.903 0.478 


Other Hexanes ............. 0.333 1.015 0.634 


Heptanes ..................... 0.692 2.453 1.478 
 • 

Methylcyclohexa ne ........ 0.242 0.842 0.451 


2,2,4-Trimethylpentane... 0.001 0.002 0.001 


Benzene ...................... 0.192 0.530 0.248 


Toluene ....................... 0.066 0.215 0.102 


Ethylbenzene ............... 0.003 0.010 0.005 


Xylenes ....................... 0.010 0.038 0.018 


C8+ Heavies ................ 0.027 0.109 0.064 


Totals ........................ 100.000 100.000 100.000 


• 
,e 

j 

I 

1 	 ADDITIONAL BETX DATA 

I Components Mole % Weight % Liq. Vol. %

I Cyclopentane 

Cyclohexane ~ J 	 2-Methylpentane ~ 3-Methylpentane 

I 

~ 

n-Hexane 

Methylcyclohexane 

J 	 2,2.4-Trimethylpentane 

Benzene 

Toluene 

Ethylbenzene

l 

• m-Xylene 

p-Xylene 

o-Xylene 

0.102 0.252 0.139 

0.304 0.903 0.478 

0.210 0.639 0.399 

0.123 0.376 0.235 

0.461 1.405 0.877 

0.242 0.842 0.451 

0.001 0.002 0.001 

0.192 0.530 0.248 

0.066 0.215 0.102 

0.003 0.010 0.005 

0.002 0.006 0.003 

0.007 0.026 0.012 

0.002 0.006 0.003 

SPECIFIC GRAVlTY @ 60/60 F, calculated................................................... 0,9765 


TOTAL GPM (Ethane Inclusive) ................................................................. 11.511 


CALCULATED BTIJ / REAL CF @ 14.73 PSlA, dry basis.................................. 1602.761 


CALCULATED BTIJ / REAL CF@ 14.73 PSIA, wet basis .................................. 1575.593 


AVERAGE MOLECULAR WEIGHT........................................................... . 28.281 


MOLAR MASS RATIO.............................................................................. 0.9765 


RELATIVE DENSITY ( G x Z (Air) / Z ), calculated ...................................... .. 0.9632 


IDEAL GROSS HEATING VALUE, BTIJ / IDEAL CF@ 14.696 PSIA.................. 1568.143 


COMPRESSIBIlJTY FACTOR (Z).............................................................. 0.99316 


PROPANE GPM ..................................................................................... 3.1309 


BUTANEGPM ....................................................................................... 2.3045 


GASOlJNE GPM (PENTANE AND HEAVlER) ......................................... .. 1.6621 


'dq,TIO" ,II (\I(II'd'l! I'!JU'\JI\\IIDlq"CI'Jllcl, il \("'II'CI'fkf'\I'F\H'··" lHI 1,IHr< 

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

J<} rill ", HI H\i (. ,\'·1:,1)\ ,TRi 

• 

• 

29 Country Acres Rd, Rlvtl'r1on. WY 82501 

Online: www.Precl"lon·Loobs.c:om 

E·mail: Intof\'Preclsion·Loobs.eOm 

Toll Fre.. N"mbtl'.: (866) 985.0866 

Client: 

Sample 10: 

Unique #: 

Sample Temperature: 

Sampled By: 

County: 

BISON ENGINEERING 

WILLIAMS 

SKUNK CREEK 1-12 

78 DEG F 

TC 

DUNN 

Components Mole % 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane ....................... 


iso-Butane ................... 


n·Butane ...................... 


iso·Pentane .................. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................•.. 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methyicyclohexane ........ 


2,2,4-Trimethylpentane ... 

Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.596 

0.000 

3.717 

46.514 

22.053 

16.952 

1.718 

5.657 

0.829 

1.021 

0.070 

0.263 

0.077 

0.061 

0.231 

0.034 

0.000 

0.015 

0.044 

0.004 

0.018 

0.125 

100.000 

Weight % 

0.893 

0.000 

3.545 

25.407 

22.578 

25.451 

3.399 

11.195 

2.037 

2.507 

0.167 

0.771 

0.222 

0.178 

0.789 

0.115 

0.000 

0.040 

0.137 

0.016 

0.066 

0.487 

100.000 

Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


Liq. Vol. % 

0.454 

0.000 

1.828 

35.242 

26.359 

20.872 

2.512 

7.971 

1.355 

1.654 

0.092 

0.483 

0.118 

0.112 

0.477 

0.062 

0.000 

0.019 

0.065 

0.008 

0.032 

0.287 

100.000 

10/11/2011 

10/11/2011 

30 PSI 

•

ONLINE 

• 
• 


ADDITIONAL BETX DATA 

Components Mole % WeiJiht % Li~. Vol. % 

Cyclopentane 0.070 0.167 0.092 

Cyclohexane 0.077 0.222 0.118 

2-Methylpentane 0.038 0.112 0.070 

3-Melhylpentane 0.023 0.066 0.041 

n-Hexane 0.263 0.771 0.483 

Melhylcyclohexane 0.034 0.115 0.062 

• 

2.2,4-Trimelhylpenlane 0.000 0.000 0.000 

Benzene 0.Q15 0.040 0.019 

Toluene 0.044 0.137 0.065 

Elhylbenzene 0.004 0.016 0.008 

m-Xylene 0.003 0.011 0.005 

p-Xylene 0.012 0.045 0.021 

o-Xylene 0.003 0.011 0.005 

SPECIFIC GRAVITY @ ~/~ F, calculated ................................................... 1.0141 


TOTAL GPM (Ethane Inclusive) ................................................................. 13.943 


CALCULATED BTU I REAL CF @ 14.73 PSIA, dry basis.................................. 1663.548 


CALCULATED BTU I REAL CF @ 14.73 PSIA, wet basis .................................. 1635.316 


AVERAGE MOLECULAR WEIGHT............................................................ 29.370 


MOLAR MASS RATIO.............................................................................. 1.0141 


RELATIVE DENSITY ( G x Z (Air) I Z ). calculated...................................... .. 1.0215 


IDEAL GROSS HEATING VALUE. BID I IDEAL CF @ 14.696 PSIA................ .. 1647.712 


COMPRESSIBILITY FACTOR (Z) .............................................................. 0.99276 


PROPANE GPM ..................................................................................... 4.6583 


BUTANEGPM .•..........•....•...•..........••.......•..........•..........••..•....•..........•... 2.3395 


GASOLINE GPM (PENTANE AND HEAVIER) ........................................... 1.0627 


• 

• 

• 

29 Country Acre5 Rd, Riverton, WY 82501 

PRECISIO~ Online: _P,..clalon-Laba.com

E-mail: Intofl.Preclalon-Laba.com 

~SiS Toll Free Numben (866) 985-0866

Client: 


Sample 10: 


Unique#: 


Sample Temperature: 


Sampled By: 


County: 


BISON ENGINEERING 

WILLIAMS 

TAT 2-1 

117 DEG F 

TC 

DUNN 

Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


10/11/2011 

10/11/2011 

17 PSI 

•

ONLINE 

Components Mole % 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane ....................... 


iso-Butane ................... 


n-Butane ...................... 


iso-Pentane .................. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................... 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane ... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.644 

0.000 

1.573 

39.023 

23.624 

20.193 

2.557 

7.945 

1.185 

1.596 

0.101 

0.369 

0.172 

0.417 

0.393 

0.099 

0.001 

0.031 

0.034 

0.002 

0.007 

0.035 

100.000 

We!iht% 

0.870 

0.000 

1.352 

19.208 

21.796 

27.321 

4.559 

14.169 

2.623 

3.532 

0.217 

0.975 

0.445 

1.101 

1.209 

0.299 

0.002 

0.075 

0.097 

0.007 

0.021 

0.121 

100.000 

Liq. Vol. % 

0.462 

0.000 

0.727 

27.788 

26.538 

23.368 

3.514 

10.521 

1.820 

2.430 

0.125 

0.637 

0.246 

0.720 

0.762 

0.168 

0.001 

0.037 

0.048 

0.004 

0.011 

0.074 

100.000 

• 

• 
I 

• 


ADDITIONAL BETX DATA 

Components Mole % Wei/iht % Li3' Vol. % 

Cyclopentane 0.101 0.217 0.125 

Cyclohexane 0.172 0.445 0.246 

2-Methylpentane 0.262 0.693 0.453 

3-Methylpentane 0.154 0.408 0.267 

n-Hexane 0.369 0.975 0.637 

Methylcyclohexane 0.099 0.299 0.168 

2,2,4-Trimethylpentane 0.001 0.002 0.001 

Benzene 0.031 0.075 0.037 

Toluene 0.034 0.097 0.048 

Ethylbenzene 0.002 0.007 0.004 

• m-Xylene 0.001 0.003 0.002 

p-Xylene 0.004 0.014 0.007 

o-Xylene 0.001 0.003 0.002 

SPECIFIC GRAVITY@60/60 F, calculated................................................... 1.1253 


TOTAL GPM (Ethane Inclusive) ................................................................. 16.864 


CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis.................................. 1874.169 


CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis .................................. 1842.251 


AVERAGE MOLECULAR WEIGHT............................................................ 32.591 


MOLAR MASS RATIO.............................................................................. 1.1253 


RELATIVE DENSITY ( G x Z (Air) / Z ), calculated ........................................ 1.1360 


IDEAL GROSS HEATING VALUE, BTU / IDEAL CF @ 14.696 PSIA................ .. 1852.257 


COMPRESSIBIUTY FACTOR (Z) .............................................................. 0.99058 


PROPANE GPM ..................................................................................... 5.5490 


BUTANEGPM ....................................................................................... 3.3329 


GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 1.6803 


• 

• 

• 

29 Country Acres Rd. Riverton. WY 82501 PRECISION2 Online. _w.Precl.'olPl-Lab••com

E.....II' '..'o(!1Precl.ion·...b••com 

~SfS Toll Free N..m.....' (861i) 985-0866

Client: 

Sample 10: 

Unique#: 

Sample Temperature: 

Sampled By: 

County: 

BISON ENGINEERING 

WILLIAMS 

WELL 32-29 

66 DEG F 

TC 

DUNN 

Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


10/11/2011 

10/11/2011 

20 PSI 

•

ONLINE 

Components Mole % 

Carbon Dioxide .•........... 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane ....................... 


iso-Butane ................... 


n-Butane ...................... 


iso·Pentane .................. 


n-Pentane .................... 


Cydopentane ............... 


n-Hexane ..................... 


Cydohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane ... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.512 

0.000 

1.570 

39.457 

27.369 

20.271 

2.013 

5.884 

0.765 

1.021 

0.054 

0.193 

0.066 

0.261 

0.240 

0.081 

0.000 

0.015 

0.073 

0.004 

0.D15 

0.136 

100.000 

Weight % 

0.724 

0.000 

1.414 

20.353 

26.461 

28.740 

3.763 

10.995 

1.776 

2.368 

0.123 

0.536 

0.180 

0.724 

0.773 

0.254 

0.000 

0.038 

0.216 

0.014 

0.050 

0.498 

100.000 

Liq. Vol. ./. 

0.372 

0.000 

0.735 

28.475 

31.158 

23.773 

2.805 

7.896 

1.192 

1.575 

0.069 

0.339 

0.096 

0,457 

0.471 

0.138 

0.000 

0.018 

0.104 

0.007 

0.024 

0.296 

100.000 

• 

• 
• 


ADDITIONAL BETX DATA 

Components Mole % Wei2ht % Liq. Vol. % 

Cyclopentane 0.054 0.123 0.069 

Cyclohexane 0.066 0.180 0.096 

• 

2-Methylpentane 0.164 0.455 0.288 

3-Methylpentane 0.097 0.268 0.169 

n-Hexane 0.193 0.536 0.339 

Methylcyclohexane 0.081 0.254 0.138 

2,2,4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.015 0.038 0.018 

Toluene 0.073 0.216 0.104 

Ethylbenzene 0.004 0.014 0.007 

m-Xylene 0.002 0.008 0.004 

p-Xylene 0.010 0.034 0.016 

o-Xylene 0.002 0.008 0.004 

SPECIFIC GRAVITY @ 60/60 F, calculated ................................................... 1.0738 


TOTAL GPM (Ethane Inclusive)................................................................. 16,499 


CALCULATED BTU / REAL CF @ 14.73 PSIA. dry basis.................................. 1796.792 


CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis .................................. 1766.229 


AVERAGE MOLECULAR WEIGHT............................................................ 31.101 


MOLAR MASS RATIO .............................................................................. 1,0738 


RELATIVE DENSITY ( G x Z (Ail) / Z ), calculated ........................................ 1.0830 


IDEAL GROSS HEATING VALUE, BTU / IDEAL CF @ 14.696 PSIA .................. 1777.412 


COMPRESSIBILITY FACTOR (Z).............................................................. 0.99149 


PROPANE GPM ..................................................................................... 5.5702 


BUTANEGPM ....................................................................................... 2.5073 


GASOLINE GPM (PENTANE AND HEAVIER) ......................................... .. 1.1204 


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

• 

• 

• 

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

E_all. IntoC!ll'r_lsion.Labs.c:om 

~SIS Toll Free Numbe.. 18(6) 985.0866

Client: 

Sample 10: 

Unique #: 

Sample Temperature: 

Sampled By: 

County: 

BISON ENGINEERING 

WILLIAMS 

WOLF 27-34 

60 DEG F 

TC 

DUNN 

Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


10/11/2011 

10/11/2011 

30 PSI 

•

ONLINE 

Components Mole % 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane .....................•. 


iso-Butane ................... 


n-Butane ...................... 


iso-Pentane .................. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................... 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.514 

0.000 

2.455 

55.961 

21.138 

11.397 

1.184 

3.503 

0.833 

1.363 

0.097 

0.357 

0.150 

0.456 

0.400 

0.082 

0.000 

0.030 

0.032 

0.002 

0.007 

0.039 

100.000 

Weight % 

0.836 

0.000 

2.541 

33.170 

23.484 

18.569 

2.543 

7.523 

2.219 

3.634 

0.250 

1.138 

0.467 

1.453 

1.481 

0.299 

0.000 

0.085 

0.110 

0.006 

0.026 

0.166 

100.000 

Liq. Vol. % 

0.406 

0.000 

1.250 

43.916 

26.169 

14.535 

1.794 

5.113 

1.409 

2.287 

0.132 

0.680 

0.236 

0.868 

0.854 

•

0.153 

0.000 

0.038 

0.050 

0.003 

0.012 

0.093 

100.000 

• 
1 

I

• 


ADDITIONAL BETX DATA 

Components Mole % Wei~ht % Liq. Vol. % 

Cyclopentane 0.097 0.250 0.132 

Cyclohexane 0.150 0.467 0.236 

2-Methylpentane 0.287 0.914 0.547 

3-Methylpentane 0.169 0.538 0.322 

n-Hexane 0.357 1.138 0.680 

Methylcyclohexane 0.082 0.299 0.153 

2.2,4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.030 0.085 0.038 

Toluene 0.032 0.110 0.050 

Ethylbenzene 0.002 0.006 0.003 

m-Xylene 0.001 0.004 0.002 

,e 	 p-Xylene 0.005 0.018 0.008 

o-Xylene 0.001 0.004 0.002 

SPECIFIC GRAVITY @ 60/60 F, calculated................................................... 0.9345 


TOTAL GPM (Ethane Inclusive)................................................................. 11.726 


CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis .................................. 1558.098 


CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis .................................. 1531.712 


AVERAGE MOLECULAR WEIGHT............................................................ 27.065 


MOLAR MASS RATIO.............................................................................. 0.9345 


RELATIVE DENSITY ( G x Z (Air) / Z ). calculated ........................................ 0.9403 


IDEAL GROSS HEATING VALUE. BTU / IDEAL CF @ 14.6% PSIA................. . 1544.831 


COMPRESSIBIUTY FACTOR (Z).............................................................. 0.99377 


PROPANE GPM ..................................................................................... 3.1318 


BUTANEGPM ...................................................................................... . 1.4882 


GASOUNE GPM (PENTANE AND HEAVIER) ......................................... .. 1.4675 


• 


• 

• 


ATTACHMENT F: ENGINE MANUFACTURER'S SPECS 


• 


• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
This section of the document has been redacted because it 

contains copyrighted information. The redacted information 

can be viewed from the hard copy of the docket, which is 

available at the EPA Region 8 Office upon request. 
• RENTAL 	 C.ATERPILLARe 

Arrangement shown 

with optional trailer 

• 

FEATURES 

EMISSIONS 

• 	EPA Tier 3 and CARB Emissions Certified for 

non-road mobile applications at all 60 Hz and 

50 Hz ratings 

CAT C9 ATAAC DIESEL ENGINE 

• Utilizes ACERT" Technology 

• Reliable, rugged, durable design 

• Field-proven in multiple applications 

worldwide 

• Four-stroke-cycle diesel engine combines 

durability with minimum weight while 

providing dependability and economy 

• 	50/60 Hz convertibility 

CAT SR4B GENERATOR 

• Designed to match performance and output 

characteristics of diesel engines 

• Permanent magnet excitation 

• 

• Segregated AC/DC, low voltage 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 

MULn·VOLTAGE DISTRIBUTION PANEL 

• Simultaneous dual voltage 

• 	load door safety switch 

• Rust-free hinges on all doors 

• Adequate space for line and plug connection 

without interference 

• Remote start and stop contacts 

SINGLE·SOURCE SUPPUER 

• Complete systems designed at Caterpillar 

ISO 9001:2000 certified facilities 

• CertHied Prototype Tested with torsional 

analysis 

WORLD~DEPRODUCTSUPPORT 

• Worldwide parts availability through the 

Caterpillar dealer network 

• With over 1,875 dealer outlets operating in 

200 countries, you're never far from the 

Caterpillar part you need. 

• 99.7% of parts orders filled within 48 hours. 

The best product support record in the industry. 

• Caterpillar dealer service technicians are 

trained to service every aspect of your electric 

power generation system. 

LEHE5329-03 

• 

•

RENTAL C.TERPILLARe 

• 

STANDARD FEATURES 

Air Inlet System Air cleaner, dual element 

Turbocharger 

Charging System Battery charger 

Heavy duty charging alternator 

Control Panel Generator controls and monitoring 

Fuel tank monitoring 

Engine controls and monitoring 

Digital displays 

Cooling System Fan and belt guards 

Base mounted radiator 

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 shunt trip 

Flemote start/stop contacts 

Shore power connections 

Enclosure Sound attenuated 

12-gauge steel 

Lockable doors 

Separate vented battery compartment 

Single point lifting 

Exterior oil and water drains with Interior valves 

Hidden exterior fuel drain 

Hand holds and steps 

Powder coated finish 

Fuel System Primary fuel flltar/Water separator 

UL142 dual wall fuel tank 1667 L (440 gan 

Radiator-mounted fuel cooler 

Generator 

i 

Brushless, permanent magnet 

Coastal corrosion protection 

Shock mounted VR6 voltage regulator 

Space heater 

UL approved 

Simultaneous three-phase 480/277 end 

240/139 voltage 

Mounting System Generator soft mounted to base 

Base contains Integral fuel tank 

Sklddable structural steel design 

110% oil and coolant spill containment 

Starting System Electric starting motor 

Battery set with disconnect switch 

Jacket water heater with thermostat, 

shut-off valves 

FACTORY INSTALLED STANDARD AND OPTIONAL EaUIPMENT 

OPTIONAL FEATURES 

Trailer Full frame support 

Indapendent tandem axle trailer frame 

with tongue 

Electric actuatad hydraulic brakes 

with rechargeable battery backup 

breakaway system. 

Overeenter mechanical parking brake 

Full length fenders 

Non-skid surface on steps 

Heavy duty sefety chains and 

grab hooks 

Reinforced 4640 kg (10,000 Ibl top 

wind drop Jack 

lEHE5329-03 2 

• 

• 
• RENTAL C~TERPILLAR· 

SPECIFICATIONS 

CAT SR4B GENERATOR 

Frame size ....................••.•.••.•....•.......... 449 

Type.......................... Permanent magnet brush less 

Construction ••.........•.....• Single bearing, close coupled 

Three-phase ......................... 12 lead reconnectable 

Insulation ••...••.. Class H with coastal insulation protection 

IP rating ................................................ 22 

Alignment....••.•.•...•.........•••...•..•...•.. Pilot shaft 

Voltage regulator ••..... 3-phase sensing with Volts-per-Hertz 

Voltage regulation •...... , ........... :!: %% steady state/:!: %% 

no load to full load 

TIF ••••.••..••...••...•.....•......•..•••...•• less than 50 

THO ......................................... less than 5% 

• 

TECHNICAL DATA 

• 


ENGINE 

C9 ATAAC, 4-stroke·cycle watercooled diesel 

Bore - mm (In) ............................... , •. 112 \4.411 

Stroke - mm (in) ..•.............•....•••.•.....• 149 (5.87) 

Displacement - l (cu inl ............... , ........... 8.8 (6371 

Compression ratio ................................... 16.1:1 

Aspiration..•..•.........•.. Turbocharged AA charge cooled 

Engine control ..••.••..•.•.......•.•..•..•.••.. ADEM1M A4 

CAT CONTROL PANEL - EMCP 3.2 

24 Volt DC Control 

NEMA 1, 1P22 enclosure 

Lockable hinged door 

Enclosure mounted 

Single location customer connector point 

16 light alarm module with alarm horn 

Electric fuel level gauge 

Consult your Caterpillar dealer for available voltages. 

X0230 

Power Rating 

60Hz 

50Hz 

ekW 

kVA 

Standby TMlRIf. Prime TMlFW. 

230 DM8502 210 DM8512 

215 DMBS04 

Engine and Container Information 

Engine model 

Container dimensions 

C9 

see chart onJ)8ge 6 

Shipping WeIght IDry) 

Unit with trailer kg ObI 6210 113,690) 

Unit without trailer 

Maximum fuel Capacity Weight 

kg ObI 4980 (10,980) 

Unit with traiier kg (Ibl 7606 (16,550) 

Unit without trailer kg UbI 6278 (13,840) 

Engine Lubricating on Capacity 

Engine Coolant Capacity with Radiator 

fuel Tank Capacity 

L(gal) 

L(gal) 

Ligal) 

40 (10.65) 

36 (9.61 

1616 (4001 

fuel Consumption L/hr (gaVt'!rl 69.2 (18.3) 64.7 (17.11 

Fuel Consumption 176% Prime) L/hr (gaVt'!r) 60.6 (13.4) 

RunnIng time @ 75% PrIme 

Sound Level 

hours 28 

Standby dBIA) 74.72 

No load @ 7 m (23 ftl dBlA) 70.20 

Prime dBIA) 73.49 

Ambient Capability Deg C(Deg Fl 43 (109.41 

LEHE5329-03 3 

• 

•

RENTAL 	 C~TERPILLAR· 

RATING DEFINITIONS AND CONDITIONS 

Meets or Exceeds International Specifications: 

• 	NEMA MGl-32.IEC 60034, eSA. 9BJ37/EEC, 72/23/EEC, 

UL 50B, UL142, IS03046/1, IS08528. 89/336/EEC 

Standby - Output available with varying load for the 

duration ofthe interruption of the normal source power. 

Standby power In accordance with IS08528. Fuel stop power 

in accordance with IS03046/1, AS2789. DIN6271, and 8S5614. 

Prime - Output available with varying load for an unlimited 

time. Prime power in accordance with IS08528. 10% overload 

power in accordance with IS0304611, AS2789, DIN6271. and 

8S5514 available on request. 

Ratings are based on SAE J1349 standard conditions. 

These ratings also apply at IS03046/1, DIN6271, and 8S5514 

standard conditions. 

Fuel fates are based on fuel oil of 35" API [@ 16" C 160" F)J 

gravity having an LHV of 42 780 kJ/kg 118,390 Btullb) when used 

at 29° C 185" F) and weighing 838.9 g/Iiter (7.001 Ib/U.S. gel). 

Additional ratings may be available for specific customer 

requirements. Consult your Caterpillar representative for details. 

• 

• 

LEHE5329-03 	 4 

• 
• RENTAL 	 C..lTERPILLARDISTRIBUTION PANEL 


CJ\TERPILLAR' 

• 

•

® 

Wiring Descriptions 

1. 800 amp main breaker 240V with 24V shunt trip 

2. 400 amp main 480V with 24V shunt trip 

3. 50 amp 240V branch breaker 

4. 20 amp 240V branch breaker 

5. 20 amp 120V branch breaker 

6. 15 amp 120V branch breaker 

7. 50 amp 240V twistlock receptacle 

8. 20 amp 240V twistlock receptacle 

9. 20 amp 120V twistlock receptacle (2x) 

10. 20 amp 120V ground fault interrupter, (2x) 

11. 	15 amp 120V ground fault interrupter, 

duplex receptacle (2x) 

12. 30 amp 120V battery charger/generator 

space heater receptacle 

13.30 amp 120V JWH receptacle 

14. Remote start/stop contacts 

15. 12.7 mm (*-) ground stud 

16. Dual voltage load connection bus board 

[6.35 mm x 101.6 mm x 101.6 mm 

(y..- x 4" x 4-) bus bars) 

• 

lEHES329-03 	 5 

• 

•

RENTAL C.TERPILLARe 

CONTAINER DIMENSIONS - TOP VIEW 


2n.8(IO.74J+--~. 

• 

1----------6239.7[:m.66)---- ~--~ 

CONTAINER DIMENSIONS - RIGHT SIDE VIEW 

......... ­ 2.251 

Overall Dimensions 

Package With Trailer 

Length 4597.4mm 181in 6248.3mm 246 in 

Width 1498.6mm 59 In 2540.0mm 100 in 

Height 2387.6mm 94 In 2882.8 mm 113.5 In 

• 

LEHE5329-03 6 

• 
• 


ATTACHMENT G: EMISSION CONTROL DEVICE 

MANUFACTURER'S SPECS 

• 


• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


C""N CIMARRON ENERGY INC. 

EMISSION CONTROL DEVICES (ECD) 

• 

Cimarron Energy Tank voe Emission Control Devices are enclosed flares that are 

low maintenance with safe reliable operation, user friendly, easy to install, and 

highly efficient. These units are engineered to capture and combust vae 

emissions from the Oil/Condensate Production Tanks with clean efficient 

destruction. Cimarron EeDs have been independently tested and certified to 

exceed the strict EPA requirements with a 99% destruction rate. 

Specifications on the next page. 

Auto Ignition systems also available . 

• 

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


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


• 

• • . }

.. .-j 

\ 

o 

mil. 

""-.0, ~ 

ElQDI\ 

Ji/nliO 

+ 

48' DIA x 302 5/fr' H9GHT, 88 ORIFICES 

EMISSION CDNTROl DEVICE 

'* >98% TVOC ORE, CERTJ.flED USEPA 40 a=R 

60, APPENDIX A. SClURCE EMMISIONS TEST 

METHODS REfERENC.E). MEETS All EPA 8t 

COPHE REGULATIONS. 

• DESTROYS OIl1CONIJENSAlE PRODUCTION 

TANK VAfIORS WI NO VISIBLE RAME. .. EXCB.LfNT OPACITY AND 5MOKB.ESS 

DPERAllON• .. REUABI.E AND OJSTOMIZABLE IGNITION• 

.. 'VERY I.J:IN CAPITAl AND OPERATING COST• .. fAS( TO OPERAlE AND MAINTAIN. 

" WD.L DfSTROY UP TO 150 MCFD @ lD ol/in Z 

1It:lD5GN1 OI!I:: 

8 

I'H'_I II. 

, ...... >ICH8X.lE(}f ~ -,-1IrSC __---:-=:c:-::=~=~-- -.IQ!'II _~~..: I ~a:' I :..,~... .......__~ ..... 

CIMARRON "-:floe 

• 
• 


ATTACHMENT H: PROCESS FLOW DIAGRAM OF 


FACILITY 


• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 

---------

• • • 

TYPICAL MANDAREE AREA 


TWO WELL PAD FACILITY PLOT PLAN 


Dakota-3 E&P Company, LLC 


Wa FBIR, North Dakota 
 .. 

PIpeline 011 PIpeline NOT TO SCALE 

8 	 GaoMoter~. _______ .. 

II TIlllkV...tBne 	 Gao ........
 I 

I 

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~ - - - - - - - -~:.-..,-.:;:.-:.:j;:''':,::,--~.: :.---;.:":.-:.: :-:.:~..~::-!:.~:: 

~---~~---.-~------------------------~-

,'d.2O'h s.,..-Jrr"d 

~~ ~I"~ 

I 

Combustor 

Enclosed 	 Gu_ I 

I

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I 

I 

I 

I 

I 

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I 

I

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, 

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

Legend 

Derma !!!!!!!!!!!! 
 WaterLine 


CIucIe Line 


FIo",1ino: 


Buried R..-,.:le LI"", 

OUSalooLine 

Tank Vapor Lillo 

I'1JII'OdOULIlle 

~""".r"'",.~'\"""'Il'""....,-_,,,,,,,,,,,..ot...._",,~r·,,~,,,,,,,,,,·,,,,,,,,,,,---~,,,,_._._.,~~_fII'~,4! "m:<JI,:V_.1_1W "'~It ,4:a;;!t'~'~, paw ,Nt'" ~~ 1:Il!I2l4, Nri"ii_"M'I'llW"l'iC"!li\III ik~_,' .1t%i!lJ\I!!lJ!M~~~'''_''I:l,''',__.. ''h'''_'__''''___________________________ 
• 


A TT ACHMENT I: PRODUCTION DECLINE CURVE 

CALCULATIONS 

• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


ATTACHMENT J: DIESEL TANK EPA TANKS 4.09D 

EMISSIONS SUMMARY 

• 


• 


Dakota·3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
__ 

• TANKS 4.0 Report • • Page I of6 

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 (yIn): 


Is Tank Underground (yIn): 


Paint Characteristics 

Shell ColorlShade: 

Shell Condition 

Breather Vent Settings 

Vacuum Settings (psig): 


Pressure Settings (psig) 


TANKS 4.0.9d 


Emissions Report - Detail Format 


Tank Indentiflcatlon and Physical Characteristics 


1000 gallon diesel tank 

Williston 

North Dakota 

Williams E&P, LLC 

Horizontal Tank 

1,000 gallon diesel tank to fuel on site 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) 

• 


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• • • 

TANKS 4.0 Report Page 2 of 6 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

TANKS 4.0.9d 

Emissions Report - Detail Format 

Liquid Contents of Storage Tank 

Mixture/Component 

Distilale fuel oil no, 2 

Month 

All 

Daily Liquid Sur!, 

Temperature (deg F) 

Avg, Min, Max, 

SO,18 39,12 60,64 

Liquid 

Bulk 

Temp 

(degF) 

44.68 

Vapor Pressure (psia) 

Avg. Min. Max, 

0.0045 0.0031 0.0061 

vapor 

Mol 

Weight 

130,0000 

Liquid 

Mass 

Fracl. 

Vapor 

Mass 

Fracl. 

Mol. 

Weighl 

188.00 

BaSIS lor Vapor Pressure 

Calculallons 

Opllon 1: VP50 • ,0045 VP60. ,0065 

filp.·//r·\PrnM:lm Filp.r;:\T:lnh4()QrI\r;:n.mllrvrlir;:nlllV htm 9/29/2011 
• • • • TANKS 4.0 Report Page 3 of6 

TANKS 4.0.9d 


Emissions Report· Detail Format 


Detail Calculations (AP-42) 


1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

Annual Emission CalcaulaHons 

Slanding losses (Ib): 

Vapor SpaCAII Volume (eu fI): 

Vapor DensUy lIb/eu H): 

Vapor Space E_nsion Facior: 

Venled Vapor Saturation Factor: 

Tank Vapor Space Volume: 

Vapor Space Volume (eu II): 

Tank Diameter (H): 

Effective Diameter (H): 

Vapor SpaCAII Oulage (II): 

TanI< Sheillangih (ft): 

vapor Densily 

Vapor Dens!!}' (Ib/eu H): 

Vapor Molecular Weight (Ibnb-mole): 

Vapor Pressure al Daily Average liqUid 

Surface Temperature (psia): 

Dally Avg. liquid Surlace Temp. (deg. R): 

Dally Average Ambient Temp. (deg. F): 

Ideal Gas Constanl R 

(psla euff I (Ib·mol-deg R)): 


liquid Bulk T emperelure (deg. 


Tanl< Painl Solar AbsorptanCAII 


Dally Total Soiar Insulallon 


Factor (BlulSQft day) 

Vapor Space Expansion Faclor 

Vapor Space Expansion Faclor: 

DaHy Vapor Temperature Range (deg. A): 

Daily Vapor Pressure Range (psla): 

Brealher Vent Press. Setllng Range(psia): 

Vapor Pressure al Dally Average liquid 

Surface Temperature (psla): 

Vapor Pressure at Dally MInimum liquid 

SurfaCAII Temperature (psia): 

Vapor Pressura al Dally Maximum liQuid 

Surface Temperature (psia): 

Dally Avg. liquid SurfaCAII Temp. (deg R): 

Dally Min. Liquid Surface Temp. (deg R): 

Dally Max. liquid SurfaCAII Temp. (deg A): 

Dally Ambient Temp. Range (deg. R): 

Vented Vapor Saluration Faclor 

Vented Vapor Saluralion Facto,· 

Vapor Pressure al Dally Average Liquid: 

Surfaca Temperature (psia): 


Vapor Space Outage (If): 


Working losses (Ib): 

Vapor Molecular Weight (lbnb-mole): 

Vapor Pressure al Daily Average lIquid 

SuriaCAII Temperature (psia): 


Annual Net Throughput (gallyr.): 


0.2654 

1l6.57t9 

0.0001 

0.0780 

0.9995 

1l6.5719 

4.1600 

7.2797 

2.0800 

10.0000 

0.0001 

130.0000 

0.0045 

509.8466 

41.5958 

10.731 

504.3458 

0.6800 

1.276.2450 

0.0780 

41.83n 

0.0036 

0.0600 

0.0045 

0.0031 

0.0067 

509.8466 

499.3872 

520.3060 

24.3583 

0.9995 

0.0045 

2.0600 

5.6720 

130.0000 

0.0045 

2,244,312.0000 

file:/IC:\Prot!ram Files\Tanks409d\summarvdisolav.htm 9/29/2011
• • • 

TANKS 4.0 Report Page 40f6

Annual Turnovers: 2,244.3120 


Turnover Factor: 0,1800 


Tank Diameter (ft): 


Working lOSS Product Factor' 


T olal Losses (Ib)' 5.9375 

file~/lr'\PrnpT~m Files\T~nks409n\sl.,m~rvnisnl~v.htm 9/29/201 I
• • • TANKS 4.0 Report Page 5 of6 

TANKS 4.0.9d 


Emissions Report - Detail Format 


Individual Tank Emission Totals 


Emissions Report for: Annual 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

I II Losses(lbs) I 

IComponents II Working Lossil Breathing Lossil Total Emissionsl 

IDistiliate fuel oil no. 2 II 5.6711 0.2711 5.941 

• 


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