• 

APPLI CA TI ON FORAN N-,.::;;.;;;.-.;;;...;;..---::...;;.l 

PSDITITLE V SYNTHETIC MINOR 

AIR QUALITY PERMIT 

WOLF CHIEF 27-34H 

AD OIL & GAS 

FA_&AoI&. 

Prepared by: 

Bison Engineering, Inc. 

1400 11th 

Helena, 

(406) 

'""" 

-- Deeemtier 29, 2011 - x, 

-­ - -­-

-
• 


~ ~OW~ij 

uU CEC DAKOTA-3 E&P COMPANY, LLC 29 2011 ~. a subsidiary orWilliams 

1001 17" Street, Suite 1200 

8P-AR Denver, CO 80202

3031527·3900 

December 29, 2011 

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

Minor NSR Pennitting Coordinator rSairpennitting@epa.gov 

• 

U.S. EPA, Region 8 


1595 Wynkoop Avenue, 8P-AR 


Denver, CO 80202-1129 

Re: Synthetic Minor Source Pennit Application for the WolfChief 27-34H Pad 

Dear Ms. Paser: 

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

Source Pennia Application for the Wolf Chief 27-34H Pad. This application is being submitted in 

accordance with the requirements ofFederal 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 

JoDeIl.Mizoue@Williams.com. 

Sincerely, 

Williams 


Dakota-3 E&P Company, LLC 


• Jt!um~E Staff Environmental Specialist 

Attachment 

cc: 	 File 

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

New Town, ND 58763-9404 

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

(letter Only) 

I 

! 

I 

t 

I, 

r 

! 

! 

I 

t 

t 

t 

t 

l 

l

, 

f 

t 

~ 

~ l' 

~' 

• 

• 


• 


UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 

Region 8 Air Program 

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

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 of this 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 infonnation 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 of application 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 suhmit information to 

following two entities: 

Minor NSR Permitting Coordinator 

U.S. EPA, Region 8 

1595 Wynkoop Avenue, 8P-AR 

Denver, CO 80202-1129 

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 

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 

Wolf Chief 27-34H Pad 

3. Type ofOperation 

Oil and Gas Production 

4. Portable Source? o Yes I2J No 

5. Temporary Source? 0 Yes I2J No 

6. NAICS Code .7. SIC Code 

213111 I 1311 

8. Physical Address: 1001 17th Street, Suite 1200 Denver, CO 80202 

9. Reservation* 

FBIR 

10. County* 

Dunn 

lla. Latitude* 

47.7011222 

11 b. Longitude* 

-102.5704266 

12a. Quarter Quarter Section * 

NENW 

12b. Section* 

27 

12c. Township* 12d. Range* 

Tl49N 

I 

R93W 

• 

• 

B. PREVIOUS PERMIT ACTIONS (Provide information in this format for each permit that has 

been issued to this facility. Provide as an attachment if additional space is necessary) 

This section ofthe permit application is not applicable. This application is for a new facility for which 

no previous permit actions have been taken. 

Facility Name on the Permit N/A 

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

I Date of the Permit Action N/A 

• 

• 

• 
• 


C. CONTACT INFORMATION 


• 


• 


Company Contact: loDell Mizoue Title: 

Staff Environmental 

Specialist 

Mailing Address: 1001 17th Street, Suite 1200 Denver, CO 80202 

Email Address: JoDell.Mizoue@Williams.com 

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

I 

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

Mailing Address 

Email Address 

Telephone Number Facsimile Number 

FaciUty Contact: Same as above Title 

Mailing Address 

Email Address 

Telephone Number Facsimile Number 

Compliance Contact: Same as above Title 

Mailing Address 

Email Address 

Telephone Number Facsimile Number 

• 

• 

D. ATTACHMENTS 


Include all 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 of all 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 of days 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, PMIO, PM2•S, sulfur oxides (SOx), nitrogen oxides (NUx), carbon monoxide (CO), volatile 

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

mist (H2S04), hydrogen sulfide (H2S), total reduced sulfur (TRS) and reduced sulfur compounds, including all 

calculations for the estimates . 

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

total. 

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

../ 	 ESA (Endangered Species Act) 

../ 	 NHPA (National Historic Preservation Act) 

• 

• 

• 
• 


E. TABLE OF ESTIMATED EMISSIONS 

The following tables provide the total emissions in tons/year for all pollutants from the calculations 

required in Section D of this form, as appropriate for the use specified at the top of the form. 

E(i) - Proposed New Facility 

Pollutant 

PM 

PM1• 

PM u 

SOx 

• NOx 

CO 

VOC 

Pb 

Fluorides 

8 2SO.. 

8 2S 

TRS 

RSC 

Potential Emissions 

(tpy) 

0.49 


0.49 


0.49 


0.14 


30.95 


60.63 


1247.50 


Negligible 

Negligible 

Negligible 

Negligible 

Negligible 

Negligible 

Proposed Allowable 

Emissions 

(tpy) 

0.60 


0.60 


0.60 


0.14 


33.34 


73.65 

49.55 

Negligible 

Negligible 

Negligible 

Negligible 

Negligible 

Negligible 

PM - Particulate Matter 

PMJO - Particulate Matter less 

than 10 microns in size 

PM2.5 - Particulate Matter less 

than 2.5 microns in size 

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic 

Compound 

Pb - Lead and lead compounds 

Fluorides - Gaseous and 

particulates 

H2S04 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur 

Compounds 

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

sources, pursuant to CAA Section 3020): 

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

(b) Kraft pulp mitis; 

(c) Portland cement plants; 

(d) Primary zinc smelters; 

(e) Iron and steel mills; 

(f) Primary aluminum ore reduction plants; 

(g) Primary copper smelters; 

• (h) Municipal incinerators capable of charging more than 

250 tons of refuse per day; 

(i) Hydrofluoric, sulfuric, or nitric acid plants; 

(j) Petroleum refineries; 

(k) Lime plants; 

(I) Phosphate rock processing plants; 

(m) Coke oven batteries; 

(n) Sulfur recovery plants; 

(0) Carbon black plants (furnace process); 

(P) Primary lead smelters; 

(q) Fuel conversion plants; 

(r) Sintering plants; 

(s) Secondary metal production plants; 

(t) Chemical process plants 

(u) Fossil-fuel boilers (or combination thereof) totaling 

more than 250 million British thermal units per hour 

heat input; 

(v) Petroleum storage and transfer units with a total 

storage capacity exceeding 300,000 barrels; 

(w) Taconite ore processing plants; 

(x) Glass fiber processing plants; 

(y) Charcoal production plants; 

(z) Fossil fuel-fired steam electric plants of more that 

250 million British thermal units per hour heat input, 

and 

(aa) Any other stationary source category which, as of 

August 7, 1980, is being regulated under section III or 

112 ofthe Act. 

• 

• 

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 

(tpyl 

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

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

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

SOx N/A N/A N/A N/A 

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

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

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

Pb N/A N/A NJA N/A 

NH3 N/A N/A N/A N/A i Fluorides N/A N/A N/A N/A 

H2SO4 N/A N/A NJA N/A 

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

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

RSC N/A NJA N/A NJA 

• 

PM - Particulate Matter 

PMlO - Particulate Matter less than 10 microns in size 

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

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic Compound 

Pb - Lead and lead compounds 

NH3 - Ammonia 

Fluorides - Gaseous and particulates 

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 determine ifthe change is 

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

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

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

Helpful Definitions from the Federal Minor NSR Rule (40 eFR 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: 

(I) 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 permit 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 dermed in 

§52.21 (b)(l6), except that the allowable emissions for any emissions unit are calculated 

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

unit's potential to emit. 

• 	 52.21(b)(1 6) - Allowable emissions means the emissions rate ofa stationary source calculated 

using the maximum rated 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 following: 

• 


(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 70fl5 

• 
• 

A. General Facility Information 

1. Company Name & Operator Name (ifdifferent): 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 (i.e., 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. 

S. 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 7 North American Industry Classification System 

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

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

Classification System (N AICS) has replaced the SIC codes, much of the Clean Air Act permitting processes 

continue to use these codes. The SIC Code for your facility can be found at the following link 7 Standard 

Industrial Classification Code (http://www.osha.gov/pls/imis/sicmanual.html). 

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 of the Indian reservation within which the facility is operating. 

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

lla & 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 SectionlSection/TownshiplRange. 

(e.g., SW V4, NE V4/S36ITIONIR21E). 

• 

Page 8 oflS 

• 
• 

B. Current Permit Information 

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

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

permit number must be included with each permit identified. 

C. 	 Contact Information 

Please provide the information requested in full. 

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

contact. 

• 


2. Operator Contact: Provide the name of the 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. 

'" 	 FORM SYNMIN 

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

SYNMIN be included with this application. 

'" 	 Narrative description of the proposed production processes. 

• 

1. The narrative description should follow the flow ofthe 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 ofchemicals, etc? 


How will the raw materials be affected by this process? 


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


Etc .... 


2. 	 The proposed operating schedule presented in terms ofhours 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 ofl5 

• 
• 

./ 	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. 


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

ofmaterial and product. 

•

./ 	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 ofraw 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. 

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

• 

Page 10 of 15 

• 
• 


Criteria Pollutant Emissions Estimates 

~ Estimates ofCurrent Actual Emissions, Current Allowable Emissions, Post-Change Uncontrolled 

Emissions, and Post-Change Allowable Emissions for the following air pollutants: particulate 

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

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

particulate), sulfuric acid mist (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/ttn/chiefletpac/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 

(lbslhr) 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 (lbslhr) 

times allowed hours (which is the number of hours 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 of pounds in a ton). 

1. 	 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 of each unit. 


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


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


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


replacement. However, this may not be a negative value. Ifthe allowable emissions ofan 


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

•

calculation. 

• 	 For each unpermitted emissions unit (i.e., 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 of15 
• ./ Modeling Analysis 

Do I need to do a modeling analysis? 

The Federal Minor New Source Review Regulations at 40 CFR 49.159(d) requires that a modeling 

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

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

Prevention ofSignificant Deterioration (PSD) increment violation. 

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

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

issued. 

• 

To facilitate the protection of the 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 of the 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) Ifyou 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@epa.gov 


303-312- 6113 


Page 13 of 15 

• 

----

----

I 

• 

What Kind ofAir Quality Modeling Analysis Is Needed? 

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

follows: 

Step 1: Qualitative Air Quality Assessment 

Step 2: Screening Modeling Analysis 

Step 3: Preliminary Modeling Analysis (refined modeling) 

Step 4: Full Impact Modeling Analysis (refined modeling) 

Step 5: PSD Increment and NAAQS Analysis 

Step 6: Additional Impact Analysis 

2. 	 Step ]: Qualitative Air Quality Assessment 

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

source would have 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/scramldispersion screening.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 'fi leant I mpact L eve s 

Pollutant Averaging Period 

1 hr 

I 3 hr S02 

! PM2.5 


PM10 


N02 


CO 


24hr 


Annual 


24 hr 


Annual 


24hr 


Annual 


1 hr 


Annual 


1 hr 


8 hr 


Class II Area SIL 


(ug/m3) 


3 ppb or 7.8 uglm.l (interim) 


25 


5 


1 


0.07 


0.06 


5 


1 


4 ppb or 7.5 uglm.l (interim) 


1 


2,000 ppb 


500ppb 


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

Class I Area SIL 

(uglm3) • 

1.0 

0.2 

0.08 I 

1.2 

0.3 I

0.2 

0.08 

0.08 

Page 14 of15 

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

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

6 should be performed based an approved protocol. 

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

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

What Should I Include In My Application IfModeling Is Necessary? 

I. 	 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 an cases, the modeling results should include the name ofthe model used, all input 

parameters, and the resulting output. Electronic copies of the 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 

and/or 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/endangered! 

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

• ./ NHPA 

The National Historic Preservation Act requires us, in consultation with State and!or Tribal Historic 

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

To expedite the approval ofyour proposed construction, we encourage you to identifY any cultural 

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

website has been provided to assist you: 

http://nrhp.focus.nps.gov/natreghome.do ?searchtype=natreghome 

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

Page 15 of 15 

• 

• 

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 

Region 8 Air Program 

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

Checklist - Synthetic Minor Limit Request 

(Form SYNMIN) 

Use of this 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 of application 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: 

Federal Minor NSR Permit Coordinator 

U.S. EPA, Region 8 

1595 Wynkoop Avenue, 8P-AR 

Denver, CO 80202-1129 

A. 	GENERAL INFORMATION 

B. ATTACHMENTS 

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

./ 	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 ofthe potential emissions of Greenhouse Gas (GHG) pollutants before and after proposed 

emission controls. 

The Tribal Environmental Contact for the specific reservation: • 

If you 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 

• 

• 

Company Name 

Dakota-3 E&P Company, LLC 

Facility Name 

WolfChief 27-34H Pad 

Company Contact or Owner Name 

JoDelI Mizoue 

Title 

Staff Environmental 

Snecialist 

Mailing Address 

100I 17th Street, Suite 1200 Denver, CO 80202 

Email Address 

JoDell.Mizoue@Williams.com 

Telephone Number 

(303) 606-4056 

! Facsimile Number 

I (303) 692-8285 
• 


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 of an 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-Enforceahle 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 of federal Clean Air Act programs that use PTE to determine whether they apply are 

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

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

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

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

Ifa source accepts a federally-enforceable limitation through a synthetic minor 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. A ITACHMENTS 

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 ofmany 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 aHow the source to avoid an otherwise 

applicable requirement. The information presented must clearly explain how the limitation affects each 

emission unit and each air pol1utant 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 of air 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. (i.e., manufacturer 

specifications). 

(iv) Other engineering calculations; or 

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

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

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

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

the number ofpounds in a ton). 

•

Item 5 - New construction projects that have the potential to emit GHG emissions of at 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 tpy on a mass basis are subject to PSD permitting requirements, even 


ifthey do not significantly increase emissions ofany 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 (C02 e), the mass emissions ofeach individual GHG 

Page 3 of4 • 
• adjusted for its Global Warming Potential (GWP) can be found at: 

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

1. Carbon dioxide (C02) 

2. Methane (CH4) and its C02e 

3. Nitrous oxide (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 
WOLF CHIEF 27-34H PAD ATTACHMENTS: 


• 

Attachment A: Application Report 

Attachment B: Emission Inventory 

Attachment C: Flashing Emissions Calculations 

Attachment D: Representative Low Pressure Oil Analytical Data 

Attachment E: Representative Gas Analysis 

Attachment F: Engine Manufacturer's Specs 

Attachment G: Emission Control Device Manufacturer's Specs 

Attachment H: Process Flow Diagram of Facility 

Attachment I: Production Decline Curve Calculations 

Attachment J: Diesel Tank EPA TANKS 4.09d Emission Summary 

• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
ATTACHMENT A: APPLICATION REPORT 


I

• 

• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


APPLICATION FOR AN NSR 


PSD/TITLE V SYNTHETIC MINOR 


AIR QUALITY PERMIT 


WOLF CHIEF 27-34H 


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 Internal Combustion or Compression Ignition Engines ....... 8 


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


6.3 Produced Casing Head Gas Emergency Utility Flare .............................. 15 


• 
 6.4 Rice Engines ............................................................................................ 16 


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


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


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


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


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


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


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


Wolf Chief 27-34H Pad 12/29/11 pg. ii 


NSR Synthetic Minor Permit Application 


Project #: WEP211324 


• 
• 

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 

• 

Wolf Chief 27-34H Pad 12/29/11 pg.iii 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


1.0 INTRODUCTION 


1.1. Summary 

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

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

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

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

Air Act. 

• 

Dakota-3 is proposing to construct and operate the Wolf Chief 27 -34H Oil and Gas 

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

permit are allowable emissions specified by requested federally enforceable permit 

conditions that limit the emissions from the facility to below the PSD and/or Title V major 

source thresholds. These limits can be found in Section 4.0 of the application. 

1.2. Site Location 

The Wolf Chief 27-34H Pad is proposed to be located in the northeast X of the 

northwest Y. Section 27, Township 149 North, Range 93 West, Dunn County, on the 

FBIR in North Dakota. 

1.3. Site Description 

At the proposed Wolf Chief 27 -34H Pad there will be six oil and gas wells that are 

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

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

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

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

1. Wolf Chief 27-34HA 

2. Wolf Chief 27-34HC 

3. Wolf Chief 27-34HD 

• 

4. Wolf Chief 27 -34HW 

5. Wolf Chief 27-34HX 

6. Wolf Chief 27 -34HZ 

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

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

names change. 

Wolf Chief 27·34H Pad 12/29111 pg.1 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

2.0 NARRATIVE DESCRIPTION 


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

Wolf Chief 27~34H Pad. For purposes of estimating emissions from this facility, the 

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

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

Inventory. 

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

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

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

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

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

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

•

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

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

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

at different times. 

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

capabilities. 

6 - Heater Treater/Separators 6 - Line-Heaters (0.75 MMBtu/hr max) 

24 - Oil Production Tanks 1 - Gasoline Recycling Pump 

6 - Produced Water Tanks 6 - Electric Lifting Units 

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

1 - Manufactured Produced Gas Flare 6 - Diesel Engines 

1 - Manufactured Enclosed Tank Vapor Combustor 

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

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

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

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

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

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

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

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

phases from each other because 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 onsite utility flare serves as an emergency backup in the event 

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

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

Wolf Chief 27 -34H 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. 

• 

Wolf Chief 27-34H 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 

Wolf Chief 27-34H Pad has been approached in a very conservative fashion. The 

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

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

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

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

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

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

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

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

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

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

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

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

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

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

of facility. 

• 

• 

Wolf Chief 27 -34H Pad 12/29/11 pg.4 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• • • 

••••••••• ••• ••• •••••••• 

• 

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

Example of Maxif!l_~11'! PTE from a Seven Well Pad 

6,000 

.~All seven wells begin 


production
 5,000 simuJtaneoUsfV 

+

R'OOO 

co • 

1000 • 

ct' • • 	 Total Production trom Seven 

WeUs on Pad i 	 • 

& 	 .4L 

2,000 :- ...... 

1,000 	 - -......-,................ 


o 

o 	 10 20 30 40 

Month 

Wolf Chief 27-34H Pad 12/29111 pg.5 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• • • • 

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 

i 

a.. 

II 2,000 

If

.. 

5th well begins production 

2nd well begins production 

1st well begins production 

-t'-Total Production from Seven Wells on Pad 

~ -12-Month Rolling Average 011 Production 2:­

-= 1,500 c -12-Month Rolling Average 011 Production Limit o 

::E 

1,000 

500 

o 

o 5 10 15 20 25 30 35 40 

Month 

Wolf Chief 27-34H Pad 12129111 pg.6 

NSR Synthetic Minor Pennit Application 

Project #: WEP211324 
• 


• 


• 


• 


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 

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

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

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

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

Wolf Chief 27 -34H 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 line­

•

heaters. Each heater is rated to a maximum capacity of 750,000 Btu/hr. The emissions 

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

3.5 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. • 

Wolf Chief 27-34H 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 Wolf Chief 27-34H Pad in 

order to obtain a synthetic minor status with regard to the NSR permitting programs. 

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

while emitting less than the PSOlTitie V major source thresholds of 250/100 tons per 

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

per year of all emitted HAPs. 

4.1 Production Storage 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: 24.45 tons 

per year of VOCs and 0.34 tons per year of HAPs. 

4.2 Reciprocating Internal Combustion or Compression Ignition Engines 

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

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

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

1111 and zzzz., as applicable. 

• 

Wolf Chief 27-34H Pad 12/29/11 pg.9 

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 are reduced by the smokeless combustion device, CO, NOx, PM, PM10, PM2.5 

and N20 emissions are created by the combustion process. These emissions estimates 

•

are calculated using AP-42 factors and applying the weight percentages of the criteria 

pollutant and greenhouse gas components from a representative gas analysis. 

5.2 Produced Casing Head Gas Emissions 

As stated in Section 3, the produced casing head gas is transferred to the gas sales 

pipeline. However, the residual gas released from the oil/gas/water emulsion in the 

heater treater will be sent to the onsite utility flare. Furthermore, 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. Oakota-3 is required to meet 

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

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

emit. • 

5.4 Natural Gas External Combustion Unit Emissions 

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

MMBtulhr heater treater line-heaters) at the facility; therefore, the emissions estimate is 

equal to the uncontrolled potential to emit. 

Wolf Chief 27-34H Pad 12/29/11 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 twelve­

• month rolling average actual emissions. The fugitive leak emissions primarily consist of 

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

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

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

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

5.7 Diesel Storage 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. 

• 


Wolf Chief 27-34H Pad 12/29/11 pg. 11 

NSR Synthetic Minor Permit 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 voe and 

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

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

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

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

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

requested proposed device(s): 

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

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


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


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


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


or an emissions control device; and 


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


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


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


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


Monitoring Requirements: 

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

one 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 standing/working/breathing losses and flashing emissions; or 


f. 	 Other methods approved by EPA. 

Wolf Chief 27-34H Pad 12129/11 pg. 12 

NSR Synthetic Minor Pennit Application 

Project #: WEP211324 

• 
• 


Recordkeeping Reguirements: 

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

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

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

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

operating period. As demonstrated in Attachment C of this application, the total VOC, 

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

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

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

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

the emission limits. 

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

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

6.2 Production Storage 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 fadlity will be controlled in 

one or more enclosed combustors and/or utility flares that are designed and operated to 

reduce the mass content of VOC (or VOC and HAP) emissions in the vapors vented to 

the device by at least 98%. 

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

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

ensure good air pollution control practices for minimizing emissions. 

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

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

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

Each enclosed combustion device will be: 

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

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

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

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

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

in °C, or ±2.5 °C; 

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

document the presence of a flame; 

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

alarm and remote notification system if the pilot flame fails; 

f. 	 Maintained in a leak-free condition; and 

g. 	 Operated in a smokeless mode. 

Wolf Chief 27-34H Pad 12/29111 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 Hame in the 


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


it was not operational, and the corrective measures taken. 


WOlf Chief 27 ·34H Pad 12/29/11 pg.14 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


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

emanating from an enclosed combustor or utility flare. 

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

include the following: 

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

ii. 	 Date(s) analyses were performed; 

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

iv. Analytical techniques or methods used; 

v. 	 Results of such analyses or measurements; and 

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

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

means that indicates the continuous ignition 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-3 will follow, for each enclosed combustion device and utility flare, the 

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

ensure good air pollution control practices for minimizing emissions. 

6.3 Produced Casing Head Gas Emergency Utility Flare 

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

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

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

flare . 

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

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

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

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

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

practices for minimizing emissions. 

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

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

maintained and operated during any time the facility is operating. 

Wolf Chief 27-34H Pad 12129/11 pg. 15 

NSR Synthetic Minor Permit Application 

Project#: WEP211324 

• 
• 

The emergency utility flare will be: 

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


and 40 CFR 63.11. 


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


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


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

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


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


in ec, or ±2.5 ec; 


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


document the presence of a flame; 


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


alarm and remote notification system 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 record keeping requirements are being 


proposed by Dakota-3. 


• 

Wolf Chief 27-34H Pad 12/29111 pg. 16 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


6.6 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 loadout operations using input 

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

Chapter 5. 

• Recordkeeping Requirements: 

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

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

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

Oakota-3 Will, at the end of each month, add the emissions for that month to the 

calculated emissions for all previous months since operations commenced, where 

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

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

months and record a new twelve-month total. 

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

emissions. 

6.7 Fugitive Emissions: Equipment Leaks 

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

hydrocarbon service at this facility. 

Work Practice and Operational Requirements: 

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

• centrifugal compressor vent, reciprocating compressor vent, instrument, meter, 

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

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

collect vapors and transport them. 

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

days after the leak is detected. 

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

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

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

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

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

Wolf Chief 27-34H Pad 12129/11 pg.17 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

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


piece of equipment in hydrocarbon service at this facility. 


Monitoring Reguirements: 

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


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


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


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


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


annual. 


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


equipment: 


i. Method 21 • 

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

Appendix A-7, Method 21; and 

b) 	If an instrument reading of 10.000 ppm or greater is measured. a leak 

is detected. 

ii. 	 Optical Gas Imaging Instrument 

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

accordance with 40 CFR Part 60, Subpart A, §60.18(i)(1) and (2) 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 

record keeping for equipment leaks; and 

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

completion of each inspection. 

Recordkeeping Reguirements: 

Wolf Chief 27-34H Pad 12/29/11 pg. 18 


NSR Synthetic Minor Permit Application 


ProjecU: 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 vac (or vac, total HAP, and any single HAP) emissions, in tons, from each piece 

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

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

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

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

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

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

months and record a new twelve-month total. 

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

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

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

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

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

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

• 


Wolf Chief 27-34H Pad 12/29/11 pg.19 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

7.0 QUALITATIVE AIR QUALITY ASSESSMENT 


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

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

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

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

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

that can minimize the effect of air mass movement. 

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

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

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

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

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

•

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

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

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

industrial activity (although industrial activity is clearly nearby). 

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

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

is not warranted. 

• 

Wolf Chief 27-34H Pad 12/29/11 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. 

• 


Wolf Chief 27-34H Pad 12/29/11 pg.21 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

9.0 NATIONAL HISTORIC PRESERVATION ACT 


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

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

affect cultural resources. 

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

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

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

information from the area immediately surrounding the facility 

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

analysis of the immediate area of the facility, a Class II or //I cultural resources inventory 

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

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

and any needed mitigation measures for those impacts. 

• 

• 

Wolf Chief 27-34H Pad 12129/11 pg.22 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

ATTACHMENT B: EMISSION INVENTORY 

• 


• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• • • • 

[ -~---~----- - 081<018:'3 E&P Company, LLC ---J 

Input Data 

GREEN =Require. Input 

RED =No input required. Thi. is a calculated value. Facility Information 

Olf Chief 27·34H Pad 

ss<>eiated Wells: 

~ olf Chief 27·34HO. 27·34HZ. 27·34HC. 27·34HX, 27· 

34HW,27.34HA oIlIItlicllly ..... 1IIt ............r. 


Not Producing Yet ~ ~1i/II(...~uctIonorlht_oflMCl_ofllltfoclll.y. __ ___ l _

MSiii 

l!!..i'Oductlori DIIIt8 

BOPD 

2745 

3949 

0.505 

_ 

In borroIo 01 011 

....... temr""lIItllnd_oI~. Bandon..._prmouolrpraduolng ..... InIht._IIoIcI .............lIon. 

doIIyjll'1lClu<l!lon 01 """ In MocI ....dor, ....oft lilt pnodlclod lindSO cloy. of production. 

PO ,....on lilt pnocIo1ocIllntUO cloy. of production. 

lMiusted BOPD 

lMiusted Produced Gas (Mscfd) 

Decline Factor 

1996 

1387 

rn... tho ......... BOPD ......... loboprodUClduolngtho ..........doc...llIcIor. 

fn,1o 10 tho ......... """" 01""" Iht l0III10 ......... 10 produc<t ..lngtho ..._Nd....... '*""'. 

OlllCondenute Tlnk Data Desc:rlPtIon 

Flash Gas Method: Proe:eu Simulator Ihtdrap ............ 10 __tho opprop_lIooh goo 1IIIIIhod. 

Proe:eu Simulator Estimated scf/bbl 40.23 lTh..cMlblfrollldlnot_u..fllllllor ..~--.. Bandon __WTlllkEmiulonSummoryOulpUt. 

Estimated Tlnk Vapors (scfd) 88271.137fn,1o 10 lilt IOIIoMIIkIICIcI oU"vapo....... Oft tho foIowIng: 1dJ\IIIod BOPD IIIIIIIIp1Iod by tho oc:MIbI_Nd on LlM I. 

Lower Heating Value 2401.97 p.-r.............(IIIIiIcI\ ofllllkvapolLlIoMd on ~ W TIIIUmiulon Sutftmory OUtput.

Molecular Weight 42.14 .........wlghtoltho IInkvapo.. 1n poundo .... poUJld.molo (MI-molo~ BIooll on W Tank Emloolon Sa..-.y Output. 

IVOC% 74.026 I\IOCW.IghUNcllonollhtllllkvaporgoo(CI+I.BIoodon __.WTlnkEmiulonSutftmoryOutput. 

!'Loc TPV/BOPD Emiuion Factor 0.613 Ie-don __ W TlI1k E_nsu_OulpUt. (Su_outputc_. a-lIIoIIonohip -.TPY ..... BOPD)

HAP% 1.046 ~wIght tr.ctIon 01 tho IIIIk vapor goo. Blood on ....._ E&P rink Emloolon Su_Output.

HAP TPY/BOPD Emission Factor 0.009 ....... on __W Tlllk EmIooion S"""""" output. (Su_ outputc_.a­..loIIonohip -.TPV ..... BOPOj 

C02% 0.26% wlghtfMcllon of tho IIIIk vapor goo. Band on _ ....W Tlllk EmIooion 8ulllmory OulpUt. 

CH4% 1.99% ~wlghtfMcllon of tho IIIIk vaporgoo. Bandon ............. WTlI1k EmIooIon s_ Output. 

H:rS Might % 0.09% faa woIgIIt......"t 01 tho IIIIk vapor goo. Blood on .........E&P Tlllk Emllloion Su..mory Output. 

H:rS ITIOIe % 0.10% firs ..........."t of tho link vapor goo. Blood on ....._ W TOIIk Em_8_Output. 

Enclosed Smokeless Combustor 

Control Destruction Efllciency 98% 

__tho ",",_omIoolon oonIroIte. 

~01_""''''''''. Th.loallxod .......... booodOhoonlnll •• 

~..,. down_lo 
• • 

Dakota-3 E&P Company, LLC 'J 

Input Data 

GREEN =Requires input 

Facility Information RED = No input required. This II a calculated value. 

Wolf Chief 27·34H Pad 


Associated Wells: 


Wolf Chief 27.34HD. 27.34HZ. 27.34HC. 27·34HX. 27· 
 [.h__h.._. I 34HW.27-34HA 

Treater Gas Data Deacrlptlon 

Btu/scf 1700.39 ~of"""""_IF"'m",,_nokl!llllN/yllt) 

Molecular Welaht 29.65 A_InOlooulorwolghtoftho """""""" goo In 1bIIHno1e.1F_ rap""'__III MWyaIo) 

SpeeiI\c Gravity 1.02 ~ _Illtil COnveltlpocllc gI\I¥IIy II> ...looulorWlighl, _rtho gravlly of tho ...nmum , ... IF",m rap_ftokl ... MWyaltj 

Average Molecular Weight 29.65 IF... m nop__goo_lyMtj 

VOC% 45.94% voc ...lght~oftho"""""goo(Nolo:Welght'A.notMolo%).IF"'m~_a.. ~) 

HAP% 1.28% HAP ~~of tho""""'" goo. (Nolo: WoIgI1t'A. not MoIo%~ (F",,.. ""__goo MWyaIoI 

C02% 0.863% C02wo1ght~ofthoWlftotrumgoo. (Nolo: WoIgI1t'A. notMolo%~ (F",,.. ",,_noklgoo MWyaliol 

CH4% 25.747% CIM~_n cAtho...a.­ _ (Nolo: WoIgI1t'A. notMolo%). IF...,.. nop_ftokl !IIIlnaIyolt) 

H~_ight% 0.000% H,!I Wllghtpon:anl cA tho...a.-!III. IFrom rap__... MWyaliol 

H2SmoIe % 0.000% H,$ ...... PI-cA tho woIo!rum goo. IF,,,m nop_IIoId!lll MWyaIo) 

Connected to sales line lIM tho drop ...... nN/ til chooH tho .......rilIo om_Ion control~ 

ControllCaPIUre Efficiency 100"/0 JWIod II! pili..... --'1Mco....cA _.ftond, control oIIIclllnc:y cA ony oppIIcoblo controII Ccomb......, pit no.., ulllItY ftora, .~ 

Treater Bumer(.) 

• 

Total Btu/hr 

• 

4500000 

Daecriptlon 

0lIl bumormfna for tho hNIIr_bu""""lln bIuI1Y••_ ............ bu""ra, odd tho.., hutInpUl togothor.

tTha bUrrw(I)1IIoro ___10 __.,710 houra porVOlt. Hours of Operation 8,760 

Truck Loading Da.crlptlon 

Oil IIlIOId throuah LACT lIM tho _ down _10"""-thoIIPPlIIPrilIo .....1IIIIhod. • olio told1hIouah. LACT no 1nJwt............-.!nod In 30-35. 


Submerged loading: dedicated normal servica 
 0.6 lIM tho _ ...... llItlochooHthollPPlIIPrilIo ....of .......1I. ThI uIInIIoft"'*>r••_.......,IMt......... IIaIed on ....of ........ I 


Molecular Weight 42.14 MoIIcIIlorw.lghtof1lnk_raln 1bIIHnoIo.""'- _ .............woIght lI ..hlng ._10"" ""'" """__ E&P Ton'" doIa.


IPl1eURuIdC pu.,..pa and Contollera [NOne' _.-:J 

IG~ol Dahydretor (None) 

I 

Vapor Pressure ...._,p........ 01 JIquId ......... po..... Plr_lnch.......... (POll) lno ....pociIIc ...lII ........... ....1o T..... 2 on Truck l<>odlng" 


Temperature 


2.30 

'...........cAbulkllquldloododln F .......... 1IO ....pocIIcdoIolt ........ _ .....___I......-....
 50.0D 

Loed Rate (bbllhr) 18D '-'*t liiio cA lquklloodod III....... por hour. 

Load Time (hrs) 1.00 rn..u... K...... 10 bIdoutono ..... (hn~ 
__ __ __ 

• • 

OillCondensale Tanks 

CasinQ Head Gas 

Treater Burner 

RICE Engine 

Truck Loadino 

Fuel Storage Tank 

Pneumatic Pump 

Pneumatic Controllers 

GIvcoI DehYdrator 

ITotaIIITP!l I I 

OillCondensete Tanks 

Casino Head Gas 

Treater Burner 

RICE Enaine 

Truck Loading 

Fuel Storage Tenk 

Pneumatic Pump 

Pneumatic Controllers 

Glycol DehYdrator 

ITotalla~ 

VOC 

1222.40 

18.19 

0.11 

6.80 

N/A 

NegliQible 

N/A 

N/A 


NIA 


1247.50 

VOC 

24.45 


18.19 


0.11 


6.80 


NlA 


Neafiaible 


N/A 

NlA 


N/A 


49.55 

• 


FacIHIy: rIDa-k;;t;:3E&P Compan~, LLC II olf Chief 27-34H Pad 


..oclated Wells: 


oIfCIIIef 27·34HD. 27-34HZ, 

27-34HC. 27-34HX, 27-34HW. 

27-34HA 

Emission Summary 

Uncontrolled Potential to Emit 

Criteria Pollutants 

HAP NOlI PM PM10 PM2.5 

17.04 N/A N/A N/A N/A 

0.51 2.93 0.19 0.19 0.19 

0.04 1.93 0.15 0.15 0.15 

1.02E-01 26.09 0.15 0.15 0.15 

N/A NIA N/A NIA NIA 

Negligible 	 N/A NIA NIA NIA 

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

N/A NIA NIA N/A N/A 

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

II 17.88 II 30.95 I I 0A9 I I 0.49 I I 0.49 

HAP 

0.34 


0.51 


0.04 


1.02E-01 


NIA 


Negligible 


N/A 

NlA 


NlA 


NOlI 

2.39 

2.93 

1.93 

26.09 

N/A 

N/A 

N/A 

N/A 


N/A 


0.99 33.34 I I I I 

Allowable Potential to Emit 

Criteria Pollutants· 

PM 

0.11 

0.19 

0.15 

0.15 

NlA 

N/A 

N/A 

N/A 

N/A 

0.80 I I 


PM10 

0.11 

0.19 

0.15 

0.15 

NIA 

NlA 

N/A 

NlA 

N/A 

0.60 

PM2.5 

0.11 

0.19 

0.15 

0.15 

N/A 

NlA 

N/A 

NlA 

N/A 

0.60 I I 

I I 

I I 

co 

N/A 

15.93 

1.62 

43.08 

NIA 

N/A 

N/A 

NIA 

N/A 

60.63 

co 

13.02 

15.93 

1.62 

43.08 

NlA 

N/A 

N/A 

NlA 

NlA 

I I 

I I 

H.s 

N/A 

NA 


N/A 


N/A 

N/A 


N/A 


N/A 

NIA 

N/A 

0.00 

HtS 


N/A 


0.00 

N/A 

NlA 

N/A 

NlA 

N/A 

NlA 

N/A 

502 

N/A 

0.00 


0.Q1 


1.24E·01 


N/A 


N/A 


N/A 


NIA 


N/A 


0.14 

502 


N/A 


0.00 


0.01 


1.24E·01 


NlA 


NIA 


N/A 


N/A 


NlA 


0.14 

• 


HCHO 


Negligible 


0.00 


Negligible 


0.10 


Nealiaible 


N/A 


Nealiaible 


NegliQible 


Nealioible 


I I 0.10 

HCHO 


Neolioible 


0.00 


Negligible 


0.10 


Negligible 


N/A 


Negligible 


Nealiaible 


Negligible 


0.10 

!'~.j.'.~"";'Y'1"::Y~"""''''''''''''''''_~'''''''f'''-~~N''''r''~ ''!''!M'!0'''''''I''O,_''''''''''''~''m!'''""",,,"..._<:,t1·.....f,..._' I\•••i""'_'_""~!:"!P"' \1I:~'I\I(/~, 

73.85 0.00 

'Emissions Of laed and lead compounds. ftuorid.., sulfuric acid mist, lotal nsduead suWur, Bod nsduead sulfur compounds ... assumed 10 be ""giligable for upstraem oil & gas operations on Ihe FBIR. 
• • 

Oit/Condensate Tanks 

Casing Head Gas 

Treater Burner 

RICE Engine 

Truck Loadina 

Fuel Slorllg8 Tank 

Pneumatic Pump 

Pneumatic Controllers 

Glvcol Dehvdrator 

7373.79 

1627.95 

No 

Potential To Emit Actual 

Greenhouse Gasesb Greenhouse Gasesb 

co2 CH. N20 cO2 CH. N20 

NIA 32.40 NIA 1162.35 0.00 0.03 

3054.12 10.20 0.00 3054.12 10.20 0.00 

2318.82 0.13 0.03 2318.82 0.13 0.03 

2.27E+02 0.34 0.07 2.27E+02 0.34 0.07 

0.00 0.00 NIA 0.00 0.00 N/A 

NfA NIA N/A NIA NlA NIA 

NIA N/A N/A NIA NIA NIA 

NIA NlA N/A NIA NlA NIA 

NIA NIA NlA NlA NlA N/A 

,Totals (TP!) II 51100.14 , I 43.07 I I 0.10 I I 7362.99 I I 10.87 I I 0.13 I 

GHG M_ Emlulona (lIlY): I 5643.81 I GHG M ••• EmIsIloM (tpy): 

COlla (tpy): 8535.58 COlla (lIlY): 

Applicable to tIM TaIIorInt Rule?: 

, 

• • 

Hydm!luorocmb..,. (HFCs). P8Iflu"""","",ns (PFCsl. and Sulfur H ..aftuorid•• (SF6) emissIOns "'" not ""'_f""" O&G producllon--.,. 

Facility: I II Dakota-3 E&P compan~!L!:£n Wolf Chis' 27·34H Pael 

",,",«i.!<tel w.a.: 

Wolf Chis' 27·34HD. 27-34HZ, 

27-341iC. 27-34HX. 21-34HW. 

27-341iA 
• • • • 

Dakota-3 E&P Company, LLC 


Wolf Chief 27·34H Pad 


Associated Wells: 


Wolf Chief 27·34HD. 27-34HZ. 27-34HC. 27-34HX. 27 ..34HW-,-27·34HA 


Tanks 

011 ProductionC19i5 -_.BOPl5.. 


Flare Gas Volumel--80,276 -Sa§] 


Lower Heating Value! 2401.91 8MSCI' 

Molecular Weight[ -.u;14--·· lli/IlHi161ii] 

voc wt Fraction' 14.03% 

VOC Emission Factor! 0.613 tpyibOpd I 

HAPs: 

Benzene wt Fractiol 

Toluene wt Fraction 

E-8enzene wt Fractio 

Xylene wt Frectio 

n·Hexane wt Fractio 

0.0285% 

0.0166% 

0.0033% 

0.0191% 

0.9045% 

2,2.4.Trimethytpentane...._~~-._., 

wt Fraction! 0.0139% 

HAP Emission Factor T.Oli9--- tpYliiOp<l] 

C02 wt Fraction! 0.26% ., 

CH4 wt Fraction! 1.99% 

+,)"'~-~"",--".. '1:''''·~~~'''''k'!'_~~-~~.,'4_'''J!>~I''''':~,~~~q~UI.~,''«1,...,,,.,.,,Ii'''_lI!'ItH~_*'''\''IIo!'I!:I~_t'!*'~~E;r_~~~___ 

Controlled emissions are calcutaled based on a ~destruclion efficiency of lhe VOC gas. 
• • • 

I~ Dakota-3 E&P Company, LLC ---- I 


Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


Tan~ -] 


CRITERIA POLLUTANT EMISSIONSa 

Uncontrolled VOCs (PTE): 

Using E&P Tanks Run: I 0.613 TPV VOCIBOPO I x 11995.43 SOPO x 

DRE 

I 0% 11222•40 TPvl 

I 

Controlled VOCs (Allowable): 

~sing E&P Tanks Run: I 0.613 TPV VOCI80PO I x 11995.43 BOPO 

--~-

x 

ORE I 98% 24.45 TPvl 

Uncontrolled HAPs (PTE): 

Using E&P Tanks Run: ORE 

0.11 Iblhr 

0.011b1hr 

0.08 Iblhr 

3.361blhr 

0.071b1hr 

0.271b1hr 

~ TPY 

3,345 scflhr 

3,345 scflhr 

3,345 scflhr 

3,345 scflhr 

3,345 scflhr 

• 

3,345 scflhr 

.. 42.14 Ibl1b-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

Benzene x 11379 scfl1b-mole x x x 0% 0.46

0% 

0% 

0% 

0% 

0% 

~ = 

E-Benzene x 11379 scf/lb-mole x x ~ x = .. 0.05

Toluene x 1/379 scfl1b-mole x x ~ x = .. 0.27

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

Xylene x 11379 scfl1b-mo1e x x ~ x = .. 0.31

2.2.4-T rimethylpentane x 11379 scf/lb-mole x x x = .. 1.20 ..!!:Qlli. 

Uncontrolled TOTAL HAPS (TPV) .. I 17.04 

Controlled HAPs (Allowable): 

3,345 scflhr 

3,345 scflhr 

3,345 scflhr 

3345 scflhr 

3,345 scflhr 

3,345 scflhr 

11379scfllb-mole 

1/379 scfllb-mole 

1/379 scf/lb-mole 

11379 scl/lb-mole 

11379 scfllb-mole 

11379 scf/Ib-mole 

-- 98% 

98% 

98% 

98% 

98% 

98% 

= O.OOlblhr 

O.OOlblhr 

0.00 Ib/hr 

0.071blhr 

O.OOlblhr 

0.01 Iblhr 

.. 42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 Ib/lb-mol 

42.14 lb/lb-moI 

Benzene x x x 0.03% x 0.01

E·Benzene x x x ~ x = .. 0.00

Toluene x x x ~ x = .. 0.01

n-Hexane x x x ~ x = 0.29

.. 

= 

Xylene x x x ~ x = 0.01

2.2.4-Trimethylpentane x x x ~ x = = 0.02

Controlled TOTAL HAPS (TPV) = 0.34
• • • • 

.~~"~-":'.,.",,... 

Oakota-3 E&P Company, LLC 

Wolf Chief 27-34H Pad 


Associated Wens: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX, 27·34HW. 27·34HA 


Tanks 

Uncontrolled NOx: 

Nox:1 0 scflhr )( I 2.402 

0.00 

BluIscf I 

Iblhr 

)( 

)( 

1MMBtull,OOO.OOO BItJ 

8760 hr!}! x I 

)( l 0.000 IbIMMBlu l 

1 lonI2ooo Ib 

0.00 

0.00 

Iblhr I 

Tpvl 

NOx Created by Combustion (Actual) 

NOx:l 3.345 scflhr x I 2.402 Btu/sct I 

0.55~1 

x 

)( 

1MMBtu/l.000,OOO Btu 

8760 hr(}'!: )( I 

)( I 0.068 IbIMMBtu I 

1 10n12ooo Ib 

0.55 

2.39 

Iblhr I 

Tpvl 

Uncontrolled PM: 

PM:I 0 scflhr x I 7.6 lb/l,OOO.ooo sct 0.00 Iblhr 

0.00 Iblhr )( 8760 hr~ x 1 tonl2000 Ib 0.00 TPV 

PM Created by Combustion (Actual) 

PM:I 3.345 scflhr )( I 7.6 Ib/1.ooo.ooo sct 0.03 Iblhr 

0.03 Iblhr x 8760 hr(}'!: )( 1 ton/2000 Ib 0.11 TPY 

\\1""'''''''';:t''''i'''~i'~!N;·,~.,_t<!"·-1t\1~:W~''~~_''<K,~ft'9'''''~~~'''''''''~~~V'J~~~~~'~'''lw'""' .. "_~~_ 
• • • • 

Dakota-3 E&P Company, LLC 


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


Uncontrolled CO: 

co:, 0 scflhr:1 x , 2,402 Btu/sci' x 1 MMBlt.Vl.000.000 Btu :J x 0.3701b1MMBIu , 0.00 lb1hr-j 

O.OOiblhr:;J x 8760 hrM -:1 x , 1 lonl2000 Ib J rnO-fl'Y, 

CO Created by Combustion (Actual) 

co:, 3,345 scllhr x I 2,402 BIt.VscfJ x 1 MMBtt.V1.000.000Btu :J x 0.370 Ib/MMBlu' ,----ur=iblhr] 

,-2;1)7 Iblhr x 8760 hrM x , 1 10012000 Ib ] , 13.02 TPV I 

"NOx. 502. and CO emisSion factors are from AP42 Table 13.5-1 

(Emission Faclors for Flare Operations) . 

r Tan~ I 

• • • 
 •


REGULATED GREENHOUSE GAS EMISSIONSb 

Dakota-3 E&P Company, LLC 


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


Tanks 

Uncombusted CO2: 

C02:' 3,345 sef"'r I x 11/379 sctnb-mole I x 

0.98 

42.14 Ibllb-mole1 

Iblhr x 

wt 

x I 0.26% I 

8760 h~ x I 

ORE 

x 0% 

1 tonl2000 Ib 

0.98 

4.30 

Ib"'r 

TPY 

C02 Created by Combustion (Actual) 

C02:1 3,345 set"'r x 1120,000.0 Ibl1.000.000 set 

401.38 IbI11r x 8760 hr~ 

401.38 IbI11r I 

x 1 lonI2OOO Ib 11758.05 TPY 

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

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


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-:HHW, 27-34HA 


• 

' 

Uncontrolled CH4: 

wt ORE 

CH4:13,34S--Sdlhr:J x ~sCtJib..mof!] x 42.14 Ibllb=iiiO!el x 11.99% 1 x 0% 7AO Iblhr 

7.40 Iblhr x 8760 hr/y!' x I 1ton/2000 Ib ..! 32.40 TPY 

Controlled CH4: (Actual) 

wt% ORE 

CH4:! ~34S --SdlhD x 11/379 sdllb-mole 1 x f3[!41611&moIi) x 11.99% I x 98% 0.15 Iblhr 1 

0.15 Iblhr x 8760 hr/yr I x 110"l2oo01b 0.65 TPY J 

Thn~ -] 

• • • • 

[ Dakota-3 E&P Company, LLC 


Wolf Chief 27 ·34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27·34HA 


[ ---- Tanks 


Uncontrolled N20: 

CH4:1 3,345 scflhr x 111379 scfllb-mole I x 

0.00 

42.14 Ibllb-molel 

Ib/hr x 

wt% 

x 10.00% I 

8760 hr~ x I 

ORE x 0% 

1 10012000 Ib 

0.00 

0.00 

Iblhr 

TPY 

N20 Created by Combustion: 

CH4:1 3,345 scfIhr x I 2.3 Ibl1 ,000.000 sef 0.01 Iblhr I 

0.01 Iblhr x 8760 hrlyr x 1 tool~Olb J O·03 __ nJ 

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

(Emission Factors for Natural Gas Combustion). 

""'<~"·~"""l"."!"Y~7''''''''''':l"",·t_~~''''''''7.'''~_~_''''~'~~~~~'~,~~~'r'--......~~\'<'.~'~~'':'''I'¥~~,~_~1''l''''''""~~~.1<t~_ 
• • 

[ Dakota-3 E&P Company, LLC 


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


Flare Gas Volumel 5,n9 scflhr J(Takes Into account the 10% of the total 

produced gas volume that is not being sold.) 

Lower Healing Value'" -1"'=7::oo~.~3~86""5:::7~1-"'B""tul""'!""scf~""1 

Avg. Molecular Weight. 29.65 Ib?l§OOi!l 

VOC WI fractlonC~:.94%-:J 

HAP WI fraction 

Benzene WI fraction 

E·Benzene WI fraction 

Toluene WI fraction 

n·Hexane WI fraction 

Xylene WI fraction 

1.28% 

0.15% 

0.01% 

0.18% 

0.84% 

0.10%_ 

Casing Head Gas I 

2,2,4·Trimethylpentaner-_-=~:r-_-" 

WI fractlonJ 0.00% 

C02 WI fractlonC-O:86%--::1 

CH4 WI fraction. 25.75% J 

Hours of Flaring fOlf 

PTE:I 

8760 hoursfyr 

Control Efflicien 98% ORE 

• 
 •
• • •


"'"\""~.J"''',~

• 


[ Dakota-3 E&P Company, LLC 

Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27·34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW, 27·34HA 


II Casing Head Gas 

CRITERIA POLLUTANT EMISSIONSa 

Controlled VOCs (PTE): 

voe:1 5,119 scf/hr )( 11/379 scfllb.mole x 

4.15 

129.64686 IbIIb·mole 1 

Ib/hr )( 

x 

8760 hr!)! 

wt% 

45.94%1 )( 

Control % 

I 98% 1 

x 11 tonl2000 Ib 

4.15 

18.19 

Ib/hr 

TPY 

Controlled VOCs (Allowable): 

voe:1 5.119 scf/hr x 111379 scfllb-mole x 

___4.15 

129.64686 Ibllb-moIe I 

Ib~ x 

)( 

8760 hrlyr I 

wt% Control % 

45.94%1 )( 1 98% 1 

x 11 tonl2000 Ib = 

4.15 

18.19 

Iblhr 

TPY 

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

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


Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


Casing Head Gas 

5.779 scfIhr 

5.779 scflhr 

5.779 scf/hr 

5.779 scflhr 

5.779 scf/hr 

5.779 scflhr 

5.779 scflhr 

Benzene 11379 scfflb-mole 0.06

1/379 scfllb-mole 

1/379 scfflb-mole 

1/379 scfllb-mole 

11379 scfllb-mole 

1/379 scfllb-mole 

7.50E-02 IbfMMscf 

x 29.64686 IbfIb-mol 

29.64686 Ibllb-mol 

29.64686 Ibllb-mol 

29.64686 Ibllb-moI 

29.64686 lb11b-mol 

29.64686 lb11b-mol 

1000000 scflMMscf 

x 0.15% 

0.01% 

0.18% 

0.84% 

0.10% 

0.00% 

x x 98% 

98% 

98% 

98% 

98% 

98% 

. '" " 0.01 Iblhr 

0.00 Ibfhr 

0.021bfhr 

0.081blhr 

0.01 Ibfhr 

O.OOlb/hr 

O.OOlb/hr 

• 

E-Benzene x x x x = • 0.00

Toluene x x x x 0.07 " 

n·Hexane x x x x .. 0.33 " 

Xylene x x x x .. 0.04 " 

2.2.4-T rimethylpenlane x x x x 0.00 " " 

Formaldehyde x x = 0.00 " 

• 

Controlled HAPs (PTE): 

Using E&P Tanks Run: 

Benzene 5.779 scflhr x 

E-Benzene 5,779 scflhr )(

Toluene 5,779 scflhr x 

n-Hexane 5.779 scf/hr x 

Xylene 5,779 scflhr x 2,2,4-Trimelhylpenlane 5779 scflhr x Formaldehyde 5.779 scflhr 

1/379 sclllb-mole 

wI% Control % 

98% 


98% 


98% 


98% 


98% 


98% 


TPY 


29.64686 Ibllb-mol 

29.64686 Ibllb-mol 

29.64686 Ibllb-mol 

29.64686 Ibllb-mol 

29.64686 Ibllb-mol 

29.64686 Ibllb-mol 

0.15% 0.06

0.01% 

0.18% 

0.84% 

0.10% 

0.00% 

x x )( 0.01 Ib/hr 

O.OOlbfhr 

0.021b/hr 

0.08 Ib/hr 

0.01 Iblhr 

0.00 Ibfhr 

0.00 Ib/hr 

'" = x )( )( = 0.00 '" x x )( = 0.07 '" x x x 0.33 '" " x x x 0.04

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

1{379 scfllb-mole 

1/379 scfflb-mole 

1/379 scfllb-mole 

11379 scfllb-mole 

1/379 scfllb-mo1e 

7.50E-02 IbfMMscf 

0.12 Iblhr x 8760 hr~ x 11 ton/2OOO Ib 1 0.51 TPY I 1 I I I I '" 

Controlled HAPs (Allowable): 

Using E&P Tanks Run: wI% Conlrol% TPY 

I 0.12 Iblhr I x I 87601n/l:! I x 11 Ion/2000 Ib I " I 0.51 TPY I 
• • • 
 •


Dakota-3 E&P Company, LLC 

Wolf Chief 27·34H Pad 


Associated Wells: 


Wolf Chief 27-34HO. 27·34HZ. 27-34HC. 27·34HX. 27-34HW. 27·34HA 


Casing Head Gas 

Uncontrolled NOx (PTE): 

NOx:! 5,779 scflhr x I 1,700 Btulset 

0.671b1hr 

x 

x 

1 Mmbluf1,OOO,OOO Slu 

8760 hr!}! x 

X 0.068 IblMMBtu I 

1 tonl2OOO Ib 

'" 0.67 

2.93 

Iblhr 

TPY 

NOx Created by Combustion (Actual): 

NOx:! 5,779 setlhr x I 1,700 Btu/set 

I 0.671blhr 

x 

x 

1 Mmblul1,OOO.OOO Slu 

8760 hrll'! x 

x 0.068 IblMMBtu I 

1 tonl2OOO Ib 

" 0.67 

2.93 

Iblhr 

TPY 

Controlled H2S (PTE): 

H2s:1 5,779 seflhr x 111379 sc:fllb-mole x 

0,00 

I29.64686 Ibllb-mole I 

Iblhr x 

x 

8760 hr!}! 

wt% Control % 

0.00%1 x I 98% 1 

x 11 tonl2000 Ib 

0.00 

0.00 

Iblhr 

TPY 

Controlled H2S (Actual): 

H,s:1 5,779 sc:flhr x 111379 sc:fllb·mole x 

0.00 

I 29.64686 Ibllb-mole 1 

Iblhr x 

x 

8760 hrll'! 

wt% Control % 

0.00%1 x I 98% 1 

x 11 tonl2000 Ib 

0.00 

0.00 

Iblhr 

TPY 

'1""":'1,·"'!"~'~oro:"'!o'~~"':!:"'~"!!'t"~iP""'i!;"'~~"!":'~~~'~"'r··,!'tli'~,~,~'?'1~~_1oI"'_"""!o ~~~"""""~I'I""'1I'!'ol"""__t'OI\"_ 
• • • • 

Oakota-3 E&P Company, LLC 


Wolf Chief 27·34H Pad 


Associated Wells: 


Wolf Chief 27·34HD. 27-34HZ. 27-34HC,27·34HX. 27-34HW, 27-34HA 


Casing Head Gas 

502 Created by Combustion (PTE): 

wt% Control % 

$021 - 5.779 scf/hr x 111379 sefnb-mole x 129.64686 Ibllb-mole 1 x 0.00%1 x 1 98% 1 0.00 IblhrJ 

0.00 Ib/hr x 8760 hrfyr x '1 ton/2000 Ib -­ 1 0.00 TPY 1 

502 Created by Combustion (Actual): 

$021 5-;7i9-~:J x 11/379 scfllb-mole x 

0.00 

1 29.64686 Ibllb-moIe I 

Ib/hr x 

x 

8760 hr/yr 

wt% Control % 

0.00%1 x 1 98% I 

x '1 ton/2OO0 Ib 

0.00 

0.00 

Ib/hr J 

TPY 1 

CO Created by Combustion (PTE): 

CO:I 5,779-dr x I 1.700 Btu/set I x 1 Mmbtull,OOO,OOOBlu X 0.370 IblMMBtu -, 3.64 Iblhr 

1-3.li4lliihr - I x 8760 hrfyrJ x 1ton/2000 Ib J 15.93 TPY 

CO Created by Combustion (Actual): 

cO:1 5;179 set/hr x 1 1,700 Btu/set I x 1 Mmbtul1,OOO,OOO Btu )( 0.3701b1MMBtu , 3.64 Ib/hr 

:U4lblhr x-8700nrlYr­ d x ,-nOilI200016 15.93 TPY-­ , 
• • • 


Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


C CaSiOgHead GaS ~---- ---~- -----­

• 


Dakota-3 E&P Company, LLC 

PM Created by Combustion (PTE): 

PM:I 5,n9 scflhr x I 7.6 IbI1,OOO.OOO scf 

0.04 Iblhr x 8760 hr~ 

0.04 

x 

Iblhr 

1 tonl2000 Ib 0.19 TPY 

PM Created by Combustion (Actual): 

PM:I 5,779 scflhr )( I 7.6 Ibl1.000.000 set 0.04 Iblhr 

0.04 Iblhr J )( L 8760 hrM:::::J x 1 IOnl2OO0 Ib 0.19 TPY 

"NOx.502. PM, & CO emission factors are from AP-42 Table 13.5-1 and Table 1.4-2 

(Emission Factors for Flare Operations and Natural Gas Combustion). 

"'i",..,,,*,,",,,,.lr~""""'","~~W:'I'\"',~~,'.~,,,:-r;,/"_,,,..."/..,,,,W'~.~,_..::r,,,~:I'. ....,..""""'\ __'·.*'~"''''_'~:'\'"'~~,~~,~'',~ ,~ M 4 "' ~ £# 1,:.'~"""'~_~ 
• • 

r Dakota-3 E&P Company, LLC 


Wolf Chief 27·34H Pad 


Associated Wells: 


Wolf Chief 27-34HO, 27·34HZ, 27·34HC, 27-34HX, 27·34HW. 27·34HA 


Casing Head Gas 

C02 (PTE): 

C02 Entrained in the Produced Gas: 

Control % 

C02:! -5;779 - Sdlhr J )( 11/379 scfllb-mole x I 29.64686 Ibllb-mole 1 x 0.86%! x I 98% I 3.90 Iblhr 

3.90 Iblhr x 8760 hr/yf x IlIonl2OOO Ib J 17.08 TPY 1 

C02 Created by Combustion: 

C02:1 5,779­ SCflhr 1 x 1120,000.0 IbI1.000.000 scf d 893.52 Iblhr :J 

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

Tolal CO2 Emitted (PTE):! 3054.72 TPY 

REGULATED GREENHOUSE GAS EMISSIONSb 

.r
 • 
• • • • 

Oakota-3 E&P Company, LLC 


C02 (Actual): 

C02 Entrained in the Produced Gas: 

wt% Control % 

c02:1--U19--SClF] x '11319 scfnb:rrioie-, x 129.64686 11i11ii=iI'IOie 1 x 0.86%1 x 1 98% 1 3.90 Iblhr 

3.90 Iblhr x r ---s760 hr,yr- I x '1 tonl2OOO Ib - r 17.08TPY I 

C02 Created by Combustion: 

c02:1 -5,119 scOiir x 1120;000:0 11i/1,OOO,OOO SCI C693.52ibihCJ 

693.52 Ib/hr x 8760 hrlyr x C7t0n72000lli :J [3037.64 TPV 

Total C02 Emitted (A1lowable):1 3054.72 TPY 

"~~'"",!1<Y'''\'''''''~>1O'-'''''~~'''~~~M';+'''.'''''''''''''':''1'l'''!'<"'''''~.''~!.'/'''!'''~''''.~i!""'I1"~\'''''~'''''''~"''~-'''*f'" l(_,"'~~~i~ 

Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27·34HW. 27-34HA 


Casing Head Gas 

Controlled CH4 (PTE): 

CH4:1 5,779 scflhr x 111319 scfnb-mole x 1 29.64686 Ibllb-mole 1 

2.33 Iblhr x 

x 

8760 hr/X!: 

wt".4 Control % 

25.75%1 x 1 98% I 

x 11 tonl2000 Ib 

2.33 

10.20 

Iblhr 

TPY 

Controlled CH4 (Actual): 

CH4:! 5,779 scflhr x 111379 scfnb-mole x I 29.64686 Ibnb-mole I 

2.33~r:::::J x 

x 

8760 hr~ 

wt% Control % 

25.75%1 x 1 98% I 

x 11 tonl2OO0 Ib 

2.33 

10.20 

Iblhr 

TPY 

'!(( 
• • • • 

Oakota-3 E&P Company, LLC 


.

C02 and N20 emission factors are from AP-42 Table 1.+2 

(Emission Factors for Natural Gas Combustion) . 

Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 


Casing Head Gas 

N20 Created by Combustion (PTE): 

N20:1 5,779 scflhr I J( I 2.2 Ibl1.000.000 set 

I 1.27E-02 Iblhr I J( I 

I = 

8760 hr!f 

!1.27E-02 IbII1r I 

I J( I 1 10012000 Ib I = I 3.18E-03 TPY I 

N20 Created by Combustion (Actual): 

N20:1 5,779 scflhr I x I 2.2 Ib/l.000.000 scf I = 11.27E-02 IbII1r I 

I 1.27E-02 IbII1r I x I 8760 hr/~ I x I 1 tonl2OOO Ib I = I 3.18E-03 TPY I 
__ 

• • • • 

I Dakota-3 E&P Company, LLC I 

Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 


Heater Treater Burners 

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

Nox:I--O:-fO-ltllMMBtU:J x 4.50 MMBtulhr I = I OM1 IIlthr -) 

rOAm Ib7lif::J x 8,760 hrfyr I x 111007200016 I n:9~iP'( 

co:! 0.08 IliIMMBiU x 4.50 MMBtulhr I ,---0.31-1-Iblh~r~ 

(f.37 IbJhr - I x Ca-;f60 hr7Yf x ,lion j 2000 Itl I r 1.623 illY 

S02:!5.88E..()4 ffi7MMl3l.i.i x r4:5<lmBtUlhr I [ 0:003 lIi7hr -) 


G6SE-03 Ibfhr· ::J x 8,760 hriyrJ x .1 tooT2000Tb I 0.012 TPYPM:, O.OT IbJMMBtu x 4.50 MMBtufhr , D~lb7firJ 

D·or-jbl~ J x 8.760 hriyr x 11 ton f 2000 Ib I em' -rpy-] 

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

Dakota-3 E&P Com 


Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 


II Heater Treater Burnera ~ 

voc:1 0.01 IblMMBtu x 4.50 MMBtulhr I = 0.024 Iblllr 

0.02 Iblllr x 8,700 hr!f x 11 ton f2000IbI = 0.106 rpv 

HAP:1 0.002 IbfMMBtu x 4.50 MMBlufhr I = 0.008 Iblhr 

la.34E-D3 Ibfhr x a,760 hr~ x 11 too f2000 Ib I 0.037 rpv 

C021117.647 IbfMMBtu x 4.50 MMBtulhr I = 155.412 Ibfhr 

1]@li§.+02 Ibfhr _ I x a,76l) hrlyr .1 x 11 too f2000Ib1 = 12,318.824 Tpy _ 
• • • • 

I Dakota-3 E&P ComE!an~, LLC I 


Wolf Chief 27 -34H Pad 


Associated Wells: 


Wolf Chief 27-34HO, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 


Heater Treater Burnera 

CH4:1 0.007 IblMMBtu x 4.50 MMBtulhr I 0.030 Iblhr 

ffi!8E-02 Iblhr:::J )( 8,760 hrlyr I x '1 ton f2000 Ib I 0.130 TPY

N20:, 0.001 Ib/MMBtu x 4.50 MMBtUlhf] I 0.006 Iblhr .. 

(S.95E=03l67fif::J x 8,760 hr¥ x I 1ton f 2000 Ib I = COJ11&fPY-­

"NOx. CO. C02. & VOC Emission Factors are from AP-42 Table 1.4-1 and 1.4-2 (Emission Factors for 

Nitrogen Oxides (N20) and Methane come from Table C-1 of Subpart W). 

"U3 NOxTPY 

C---u2---coTPv:J 

r-o:Jll-s02f1>y:J 

C:~F)t..ffpy 

0:11 VOC TPY 

0.04 HAPTPY 

[23'18:82 C(j2TPY:J 

CI[f3·CH4TPY 

0.03 N20TPY 

·"-·~""i'\if"-""r<:0·"""",'J&'~of')'_~'N'!!"'''~V'''?'~J'''''~,''~->'• .,;,.".,..., ..'''r'~~""M!Q/'-."__'1't'__",,_.,""'~~"~m__,,l""~__~'1'._,_'''''' 
• • • • 

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


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 


II· Truck Loadout Emission Calculation-~ 

Saturation Vapor Molecular Temp + Load Loss 

Factor (5) Pressure(P) Welght (MW) 460 Ib/1000 gal 

12.46 I x I 0.60 I x I 2.30 J x I 42.14 I I I 510.00 I =I 1.42 

LL Truck Load Load Time Total Gas 


Ib/1,000 gal Rate bbllhr hrs gal/bbl Emissions Ib/hr 


1.42 I x I 180.00 I I I 1.00 42.00 10.74 I x I I =I 1 

LL Annual Emissions Uncontrolled 

1b/1,000 gal bbl/yr gallbbl Ib/ton TPY C3+ VOC tpy 

1.42 J x I 728331.84 1 x I 42.00 I I I 2000.00 I =I 21.72 I I 16.08 

VOC 


Emissions 


Uncontrolled Control % TPY 


16.08 I I 100% I I 0.00 .1 I _ Q.O«L ] 

==== 

• • • • 

=-== 


LL Annual Emissions Uncontrolled 

Ibl1,000 gal bbllyr sallbbl Iblton TPY 

1.42 I x I 728331.84 I x I 42.00 I I I 2000.00 I = I 21.72 I ~ 0.23 '

HAPs 

Emissions I 

Uncontrolled Control % TPY 

0.23 I 100% 0.00 0.00 I I I 1 I 1 

LL Annual Emissions Uncontrolled 

Ibl1,000 gal bbVyr ~allbb' Iblton TPY C02tpy 

1.42 I x I 728331.84 I x I 42.00 I I I 2000.00 I =I 21.72 I I 0.06 

CO2 

Emissions 


Uncontrolled Control % TPY 


0.06 I 100% 0.00 0.00 1 I I I I I 

LL Annual Emissions Uncontrolled 

Ibl1 ,000 gal bbllyr sallbbl Iblton TPY CH4tpy 

1.42 I x I 728331.84 1x I 42.00 I I I 2000.00 I =I 21.72 I 0.43 1 

CH4 

Emissions 


Uncontrolled Control % TPY 


0.43 I I 100% J J 0.00 I I 0.00 I 
• • 

II Oakota-3 E&P Company, LLC I


II RICE Input Data I


Combined Diesel Engines 

Hours of Operation 

Maximum HP Rati~ 

NOxg/hp-hr 

CO g/h~hr 

S02 glhp-hr 

PM g/hp-hr 

[VOC g/hp-hr 

HAP g/bh-hr 

C02g bh-hr 

CH4 gbh-hr 

N20 g/hp-hr 

• 

87S0 

1650 

1.49E+00 

2.61E+OO 

4.S2E-06 

4.8SE-OS 

1.42E-01 

1.02E-OS 

2.54E-03 

2.10E-02 

4.20E-03 

• 

Description 

Engine" a.umed to operate ',760 houra per yaar. 

~nufactuflr GUlrantee (40 CFR 13 Subpart" requirements), ... Altlc:hment F 

Manufacturer Gulrantee (40 CFR 13 Subpart III requlrementt}, I ..Aftllchment F 

~P-42 Table 3.3-1 

"P-42 Tlble 3.3·1 

Manufactuflr Guarantee (40 CFR 13 Subpart IHI requirements), 1M Aftllchment F 

AP-42 Table 3.3-1 

~P-42 Tlble 3.3·1 

i«I CFR 98 Subpart C, Table Co2 

40 CFR 98 Subpart C, Table Co2 

Recycle Pump Description 

Hours of Operation 8760 Enlline " I.umed to operate 8,760 houra par yor. 

Maximum HP Rating 48 Manufacturer'. maximum hp rating. 

NOx~hr 4.99E+OO ~2 Tlble 3.3-1 

CO g/hp-hr 3.1SE+OO AP-42 Tibia 3.3-1 

502 g/hp-hr 2.68E-01 ~2T.bIe 3.3-1 

PM g/hp-hr 3.27E-01 IAP-42 Tibia 3.3-1 

rvOC glhp-hr 9.80E+OO 1AP-42 Tabla 3.3·1 

HAP g/hp-hr 2.20E-01 ~P-42 Table 3.3·1 

C02 glbh-hr 4.90E+02 AP-42 Table 3.3-1 

CH4 g/hp-hr 2.10E-02 leo CFR 98 SubpartC, Tibia C·2 

N20 g/hp-hr 4.20E-03 i«I CFR 98 Subplrt C, Table (;,2 
• • 

[ Dakota-3 E&P Company, LLC 


.. • 


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD, 27-34HZ, 27-34HC, 27-34HX, 27-34HW, 27-34HA 


[ Reciprocating Engine EmisSions - - - - - - - - ­

!;NGINE #1 

1650 IMAX HP 

HOx; 1.49E+OO IlIHP-HR I x 1650 HP x 111b 1453.6Ilrams I S.43E+OO Iblhr x 8760 hr~ x 1 ton 12000lb I " 2.38E+01 NOx TPY 

£Q;, 2_61E+OO IlIHP-HRI x 1650 HP x 11 Ib 1453.6 srams I 9.50E+OO Iblhr x 8760 hr~ x 1 ton 12000lbI '" 4.16E+01 CO TPY 

S02: U2E..­ !l!!:!P-HRI x 1650 HP x 11 Ib I 453.6 l!rams I 1.84E..oS Iblhr x 8760 hr~ x 1 ton 120001bl 7.20E-05 S02 TPY 

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

~ 1.42E..o1 !l!!:!P-HRI x 1650 HP x 11 Ib I 453.6 llrams S.16E..o1 Iblhr x 6760 hr/~ x 1 ton 12000lb I 2.26E+OO VOC TPY 

~ 1.02E..oa !l!!:!p-HRI x 1650 HP x 11 Ib I 453.S !!rams 3.71E..o8 Iblhr x 6760 hr~ x 1 ton 12000lbl 1.63E-05 HCHO TPY 

~ 2.54E..o3 IlIHPHRI x 1650IHP x 11 Ib I 453.6 l!rams 9.22E..03 Iblhr x 8760 h~ x 1 ton I 20001b I 4.04E-02 CO2 

CH4: 2.10E..o2 !l!!:!P-HRI x 1650 HP x 11 Ib 1453.6 !!rams 7.84E..o2 Iblhr x 8760 h~ x 1 ton 12000lb I 3.35E-01 CH4 

H2O: 4.20E..o3 glHP-HRj x 1850 HP x '1 Ib 1453.6 grams 1.S3E..o2 Iblhr x 8760 hr/yr x 1 ton 12000lb j 6.69E-02 N20 
• • • • 

Dakota-3 E&P Company, LLC 


Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD. 27-34HZ. 27-34HC. 27-34HX. 27-34HW. 27-34HA 


[ Reciprocating Engine Emissions 

ENGINE #2 

,--.a::JMAX HP 

Hax: I U9E+OO gIHP-HR! x 48 HP x 11tb/453.6gramsl x 0.53 tblhr x I 8760 hrlyr x 11ton/2000lbl = 12.31E+OO NOXTPY:J 

~ 13.18E+00 glHP-HRI x 48 HP x !1lb/453.6gramsl x I 0.33 Iblhr x I 8760 hrlyr x 11 ton I 2000lb I =11.46E+OO COTPY 

I 2.88E.o1 glHP-HRI x 48 HP x 111b 1453.6 grams I" 2.84E.o2 Iblhr x I 8760 hr/y! x 11 ton 12000lbl =I 1.24E-01 S02 TPY 

fM.i. 3.27E-01----g?HP:tiRI x 48 HP x 11 Ib 1453.6 grams I I 3.48E.o2 Iblhr x I 8760 hrlyr x 11 ton 12000IbI = I 1.52E-01 PM TPY :J 

VQC: I 9.80E+OO gtHP-HRI x 48 HP x 11 Ib 1453.6 grams I x I 1.04 Iblhr x I 8760 hr/y! x 11 Ion 12000lbI = I 4.54E+OO VOC TPY 

I 2.20E..o1 gtHP=HR] x4rHO x 11tb 1453.6 grams I 0.02 Iblhr x I 8760 hr/y! x 11 ton 12000Ibl = I 1.02E-01 HAP TPY 

&Qi;: I 4.90E+02 g/Hp-HRI x 48 HP x 111b 1453.6 grams I .. I S.18E+01 Iblhr x I 8760 hr/yr x 1110n 12000lbl = I 2.27E+02 C02 fPY 

CH4: r 2.10E.o2 gtHP-HRI x 48 HP x 11 Ib 1453.6 giiiliS] 2.22E.o3 Iblhr x I 8760 hr/yr x 11 ton 12000lbl = I 9.73E-03 CH4 fpy 

!!mi. I 4.20E..o3 g!Hp=HRI x 48 HP x 11 Ib 1453.6 grams I , 4.441:-04 Iblhr x I 8760 hr/yr x '1 Ion 12000lb , .. , 1.95E-03 N20 TPY 
• • • • 

Wolf Chief 27-34H Pad 


Associated Wells: 


Wolf Chief 27-34HD, 27-34HZ. 27-34HC. 27-34HX, 27-34HW. 27-34HA 


Oakota-3 E&P Company, LLC 


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

TOTALS 

I 2.61E+01 

I 4.31E+01 

I 1.24E.o1 

I 1.52E.o1 

J 6.80E+OO 

1.02E.o1 

2.27E+02 

3.44E.o1 

6.89E.o2 

NOx TPY 

co TPY 

S02 TPY 

PM TPY 

VOC TPY 

HAPTPY 

C02 TPY 

CH4 TPY 

H20 TPY 

---­

., __.".,.. "~ __ ,~ •• ,.~__n'O>~"__ '~_''''''''' ______'''''<_'_'__-'_'''_ __""____...,.,._,~~I'I,,,~,..,.,~""..,__ 
• 


ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS 

• E&P Tanks Emission Summary 

• E&P Tanks Linear Relationship (Emission Factor) 

• 

• 

Dakola-3 Eap Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


Mandaree Field 1000 BOPD wt% 

****************************************************************************************** * Pro;ect setup Information * 

****************************************************************************************** 

project File : y:\projects\williams Exploration & production WEP\WEP211324 Ft. Berthold 

IR well work\E&P Tanks\Mandaree Field 1000 BOPD.ept Flowsheet selection oil Tank with Separator calculation Method RVP Distillation 

control Efficiency 100.0% 

Known Separator Stream LOW Pressure oil 

Entering Air composition NO 

Filed Name Mandaree 


well Name Cross 2-13H and Patricia charging 4-15H Averages
 permit Number Dakota-3 E&P Company, LLC 

Date 9/24/2010 

****************************************************************************************** 

* Data Input * 

• 
 ****************************************************************************************** 


Separator Pressure 51. 00 Cps i g] 
 sep~rator Temperature 82.50[FJ
 Amblent Pressure 14.70[psia]
 Ambient Temperature 70.00[F] CI0+ SG 0.8000 

CI0+ MW 235.14 

Low Pressure oil ---------------------------------------------------------------------­ NO. Component wt % 

1 H2S 0.0014 

2 02 0.0000 

3 co2 0.0042 

4 N2 0.0015 

5 Cl 0.0320 

6 C2 0.3654 

7 c3 1.2089 

8 i -C4 O. 3443 

9 n-C4 1.5191 

10 i-c5 0.6508 

11 n-c5 1.2185 

12 c6 1.3933 

13 C7 6.7524 

14 C8 15.9338 

15 C9 14.3170 

16 CI0+ 53.7971 

17 Benzene 0.0479 

18 Toluene 0.0997 

19 E-Benzene 0.0600 

20 xylenes 0.3998 

21 n-C6 1.4864 

22 224Trimethylp 0.3663 

.. Sales oil ----------------------------------------------------------------------------­ production Rate 1000[bbl/day] Days of Annual operation 365 [days/year] API Gravity 41.85 

Reid vapor pressure 5.90[psia] 

****************************************************************************************** 

* calculation Results * 

****************************************************************************************** 

-- Emission Summary ---------------------------------------------------------------------­ Item uncontrolled uncontrolled 

[ton/yr] [1 b/hr] 


page 1---------------------------------------------------------------- E&P TANK 


Total HAPs 8.550 1.952 

Total HC 812.744 185.558 


vocs, C2+ 796.480 181.845 


VOCs, c3+ 612.595 139.862 


page 1 

• 

• 

Mandaree Field 1000 SOPO wt% 

uncontrolled Recovery Info. 

Vapor 40.2300 [MSCFO]

HC Vapor 40.0300 [MSCFO]

GOR 40.23 [sCF/bbl] 

Emission composition ----------------------------------------------------­ NO Component uncontrolled uncontrolled 

[ton/yr] [lb/hr]

1 H2S 0.689 0.157 

2 02 0.000 0.000 

3 C02 2.160 0.493 

4 N2 0.786 0.179 

5 C1 16.264 3.713 

6 c2 183.886 41.983 

7 c3 375.375 85.702 

8 i-C4 37.149 8.482 

9 n-C4 112.787 25.750 

10 ;-C5 17.863 4.078 

11 n-c5 24.862 5.676 

12 C6 8.648 1.974 

13 

14 

C7 

C8 

13.803 

10.281 

3.151 

2.347 

•

15 C9 3.270 0.747 

16 C10+ 0.004 0.001 

17 Benzene 0.234 0.053 

18 Toluene 0.136 0.031 

19 E-Benzene 0.027 0.006 

20 xylenes 0.156 0.036 

21 n-C6 7.394 1.688 

22 224Trimethylp 0.604 0.138 

Total 816.378 186.388 

stream Data -----------------------------------.---------------------------------------­ NO. Component MW LP Oil Flash oil sale oil Flash Gas w&s Gas Total Emissions 


wt % wt % wt % . wt % wt % wt % 

1 H2S 34.80 0.0014 0.0010 0.0000 0.0873 0.0856 0.0861 

2 02 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 

3 CO2 44.01 0.0042 0.0020 0.0000 0.4818 0.1765 0.2642 

4 N2 28.01 0.0015 0.0001 0.0000 0.3044 0.0123 0.0962 

5 C1 16.04 0.0320 0.0079 0.0000 5.2226 0.6866 1.9891 

6 c2 30.07 0.3654 0.2356 0.0039 28.3624 20.1288 22.4930 

7 c3 44.10 1.2089 1.0468 0.4786 36.1613 49.8497 45.9192 

8 i-c4 58.12 0.3443 0.3257 0.2757 4.3503 4.6218 4.5438 

9 n-C4 58.12 1. 5191 1.4623 1.3185 13.7647 13.8076 13.7953 

10 ;-C5 72.15 0.6508 0.6432 0.6257 2.2771 2.1480 2.1850 

11 n-C5 72 .15 1.2185 1.2094 1.1888 3.1795 2.9854 3.0410 

12 c6 86.16 1.3933 1. 3945 1. 3984 1.1369 1.0640 1.0850 

13 C7 100.20 6.7524 6.7753 6.8342 1.8207 1.7133 1. 7442 

14 C8 114.23 15.9338 16.0015 16.1730 1. 3430 1.2744 1.2941 

15 C9 128.28 14.3170 14.3815 14.5440 0.4133 0.4189 0.4174 

16 C10+ 235.14 53.7971 54.0465 54.6758 0.0006 0.0005 0.0006 

17 Benzene 78.11 0.0479 0.0480 0.0483 0.0298 0.0281 0.0285 

18 Toluene 92.13 0.0997 0.1001 0.1011 0.0174 0.0165 0.0166 

19 E-Benzene 106.17 0.0600 0.0603 0.0610 0.0035 0.0032 0.0033 

20 xylenes 106.17 0.3998 0.4016 0.4059 0.0196 0.0187 0.0191 • 

21 n-C6 86.18 1.4864 1.4889 1.4959 0.9466 0.8874 0.9045 

22 224Trimethylp 114.24 0.3663 0.3677 0.3711 0.0772 0.0726 0.0739 

MW 143.08 144.90 148.98 39.02 43.55 42.14 

Stream Mole Ratio 1.0000 0.9829 0.9448 0.0171 0.0381 0.0552 

Heating value [BTU/SCF] 2225.52 2481.29 2401.97 

Gas Gravity [Gas/Ai r] 1. 35 1.50 1.45 

Bubble Pt. @ 100F [psia] 32.28 20.39 7.37 

Page 2---------------------------------------------------------------- E&P TANK 

RVP @ 100F [psia] 15.35 12.04 6.01 

Spec. Gravity @ 100F 0.677 0.678 0.680 

• 

page 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,Q Model, RVP Distillation Column 

As shown below, the E&P Tanks summary output has a linear relationship with the production rate 

of the oil with the given inputs listed below, 

Inputs: 

Low pressure oil from average of 2 representative Mandaree Field Dakota-3 Wells 

Separator: 51 psig, 83 degF 

Flash Valve: 13,7 psia, 50 degF 

Sales Oil: API Gravity 41,9, Reid Vapor Pressure 5,90 psia, 365 days/year 

• 

Outputs: 

Oil Production Rates (bbllday) (P) 0 50 100 300 1000 

Emission (tons/yr) 

Total HC 0 40,6372 81.2744 243.8232 812.744 

VOCs, C3+ 0 30.62975 61.2595 183.7785 612.595 

Total HAPs 0 0.4275 0.855 2,565 8.55 

VOC (C3+) Emission Factor: 0.6126 tpy/BOPD 

HAP Emission Factor: 0.00855 tpy/BOPD 

Tank Emissions by Production Rate 

.....-Total HAPs 

_VOCs,C3+ 

- Linear (Total HAPs) 

- Linear (VOCs, C3+) 

bbl/day 

• 

700 

600 

... 500 

II 400 

~ 300 c 

0 200 - 100 

0 

0 500 1000 1500 

• 

• 

ATTACHMENT D: 	 REPRESENTATIVE LOW PRESSURE OIL 

ANALYTICAL DATA 

• 


• 


Dakota-3 E&P Company. LLC. 

NSR'Synthetic Minor Application 

WEP211324 

• 
• 


• 


• 


• 


Laboratory • uas Measurement 

Emissions Testing • Sample Collection 

:A2LA Accredited • I'<4[;LAP Ilu:n:dlted • CPA Ccrtlfled 

19 Country Acres Rd. Rlv.,rton. \flY 81M)) • Toll f'n:." (866) 985-0866 • £-m..n, Info(ii ....,dslon-ubs.c:om • Online: www.Predslon.t.a.....cOlll 

EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY 

Company .................... ZENERGY 


Lab Number ................ CR-I0330 Study Number .......... CR-2 


Date Sampled .............. 7-15-2010 Date Tested ............. 7-23-2010 


Sample Identification .................... CROSS 2-13 H CRUDE Oil 


Sample Location .......... MONTANA. 

Sample Pressure ......... 22 PSIG Sample Temperature .... 95 F 

Type Sample ............... SPOT County ...................... DUNN 

Test method ................ GPA-2286 Sampling Method........ yz PISTON 

Components Mole % Weight % Uq. Vol. % 

Hydrogen Sulfide .......... 0.003 0.001 0.001 

Oxygen ...................... 0.000 0.000 0.000 

Carbon Dioxide ............ 0.013 0.004 0.004 

Nitrogen ..................... 0.007 0.001 0.001 

Methane ..................... 0.180 0.021 0.050 

Ethane ....................... 1.602 0.342 0.709 

Propane ..................... 4.036 1.264 1.839 

iso-Butane .................. 0.855 0.353 0.463 

n-Butane .................... 3.974 1.640 2.072 

iso-Pentane ................ 1.378 0.706 0.833 

n-Pentane ................... 2.569 1.316 1.540 

Hexanes ..................... 2.510 1.536 1.707 

Heptanes .................... 10.694 7.610 8.159 

Octanes ..................... 19.351 15.699 16.394 

Nonanes ..................... 17.072 15.551 15.886 

Decanes+ ................... 31.435 51.099 47.376 

Benzene ...................... 0.093 0.052 0.043 

Toluene ....................... 0.166 0.109 0.092 

Ethylbenzene ............... 0.104 0.078 0.066 

Xylenes ....................... 0.618 0.466 0.397 

n-Hexane .................... 2.798 1.712 1.903 

2,2,4-Trimethylpentane ... 0.542 0.440 0.466 

TOTALS ..................... 100.000 100.000 100.000 
• 

ADDITIONAL BETX DATA 

Com£onents Mole % Weight % Liq. Vol. % 

2-Methylpentane 1.486 0.910 1.011 

3-Methylpentane 1.024 0.627 0.696 

n-Hexane 2.798 1.712 1.903 

2,2,4-Trimethylpentane 0.542 0.440 0.466 

Benzene 0.093 0.052 0.043 

Toluene 0.166 0.109 0.092 

Ethylbenzene 0.104 0.078 0.066 

m-Xylene 0.066 0.050 0.042 

p-Xylene 0.436 0.329 0.280 

a-Xylene 0.116 0.087 0.074 • 

API GRAVITY AT 60/60 F, calculated ........................................................................ 60.3 


SPECIFIC GRAVITY AT 60/60 F. calculated .............................................................. 0.7378 


RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.7958 


AVERAGE MOLECULAR WEIGHT .......................................................................... 140.803 


AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 228.881 


TRUE VAPOR PRESSURE AT 100 F. PSIA, calculated ................................................ 33.400 


AVERAGE BOILING POINT, F ................................................................................. 299.063 


CUBIC FEET OF GAS I GALLON OF LIQUID. as Ideal Gas .......................................... 19.106 


BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 122456.887 


LBS I GALLON OF LIQUID. calculated ...................................................................... 6.152 


'\( n', J I<)"., 'ILL ( ALU. LATH lNS PERFORJ\IEO lSI:,(, PHYSIC '\.1 COl\:q\N r~ rROi\1 GP". 214~ 09. l'Hl-. J'\.BU·" 

(IF PHYSIC '\.1. CONSTANTS FOR HYDR()(\RB( lNS "."10 (lTHLR « )\!P( llNDS (IF lNTf-.RFSJ 

f() 1'1 IE )\\TI RAJ C;,'\.S l!\OlSTR, • 

• 
• 


EXTENDED HYDROCARBON LIQUID STUDIES 

CERTIFIC\TE ()[. ANAL\'SlS 

Company................ PRECISION ANALYSIS 

Lab Number............. CR-10330 Study Number........... . CR-2B 

Date Sampled ............. 7-15-2010 Date Tested.............. 7-22-2010 


Sample Identification ................ ZENERGV CROSS 2-13 H CRUDE OIL 


Sample Location ....... .. MONTANA. 


• 

Sample Pressure .......... N/A Sample Temperature .. .. N/A 

Flowrate................... N/A County.................... . DUNN 

I-QUART 

Test Method.............. VARIOUS 	 Sample Container ........ BOTTLE 


TEST PERFORMED 

API GRAVITY AT 60/60 F (ASTM D-287), observed ...................... 


SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated ........ .. 


REID VAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 


TOTAL SULFUR CONTENT (ASTM D-5453), PPMW ................ .. 


TRUE VAPOR PRESSURE (ASTM D-2889), PSIA AT 100 F ........... 

BASIC SEDIMENT AND WATER CONTENT, % BY VOLUME.... 

COPPER STRIP CORROSION (ASTM D-130), 1 HOUR AT 100 F........... 

FREE WATER, observed ........................................................ . 

• 

RESULTS 

42.5 

0.8132 

5.2 PSIG 

658.98 	 PPMW 

N/A 

N/A 

N/A 

N/A 

NOTATION' ALL TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY 

OUTLINED BY THE AMERICAN SOCIEn' FOR TESTING AND MATER1A1.S (ASTM) . 

• 

LaboralO!), , Gas I'lcuuranull 

[mluiuru Tullng • Sa... ,..., CoIiec.liGn • 

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

3 :;' 

(I 100000 200000 250000 

2.6671 

=~:>..ilLJ-----3.6321 

~·-~-------------------------------4.%91 

====;..5..5il8L_______ ___5.608lDecane (Cl0) 

-:-----~~------------7.0831 

==::::"[6331---------8.4521 

;;::;-;:-:--------------9.7241 

~FF"~------------ 10.9111 

------~---12.031! 

-------13.088! 

_'1"zII'rt---14,089! 

rncn--15.0411 

15.947 ! o-Ietphenyl 

Intensity 

• 

• 

• 
• 


• 


• 


• 


Company ................... . 


Lab Number ............... . 


Date Sampled ............ .. 


Sample Identification .................. .. 


Laboratory • Gas Measurement 

Emissions Testing • Sample Collection 

A2LA ~c(.;redJted • !'ICtAl" ~(.cn.:dlted • EPA Certified 

29 Counlry Acres Rd. RI""rton. 1o\'Y 82501 • Toll Frec. (866) 985.0866 • 1.-.....11: Info0 Freclslon-Labs.com • Onlln"" www......c:bfon-La....co... 

EXTENDED HYDROCARBON (GLYCALC) UQUID STUDY 

Study Number.......... CR-3 

Date Tested ............ . 7-23·2010 

PATRICIA CHARGING 4-15 HCRUDE Oil 

Sample Location .......... 


Sample Pressure ......... 


Type Sample ............... 


Test method ................ 


Hydrogen Sulfide .......... 


Oxygen ...................... 


Carbon Dioxide ............ 


Nitrogen ..................... 


Methane ..................... 


Ethane ....................... 


Propane ..................... 


iso-Butane .................. 


n-Butane .................... 


iso-Pentane ................ 


n-Pentane ................... 


Hexanes ..................... 


Heptanes .................... 


Octanes ..................... 


Nonanes ..................... 


Decanes+ ................... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


n-Hexane .................... 


2,2,4· Trimethylpentane ... 


TOTALS ..................... 


ZENERGY 

CR-10330 

7-15-2010 

MONTANA. 

80 PSIG 

SPOT 

GPA·2286 

Components Mole % 

0.008 

0.000 

0.014 

0.008 

0.398 

1.921 

3.914 

0.862 

3.606 

1.238 

2.329 

2.180 

8.849 

21.103 

15.296 

34.917 

0.085 

0.148 

0.060 

0.473 

2.204 

0.387 

100.000 

Sample Temperature .... 

County ...................... 

Sampling Method........ 

70 F 

DUNN 

yz PISTON 

Weight % 

0.002 

Liq. Vol. % 

0.002 

0.000 0.000 

0.004 0.004 

0.001 0.001 

0.043 0.107 

0.387 0.811 

1.155 1.702 

0.335 0.445 

1.403 1.795 

0.598 0.715 

1.125 1.333 

1.257 1.415 

5.934 6.445 

16.133 17.068 

13.130 13.589 

56.412 52.378 

0.044 0.038 

0.091 0.078 

0.043 0.037 

0.336 0.290 

1.271 1.431 

0.296 0.317 

100.000 100.000 
• 

ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

2-Methylpentane 1.272 0.734 0.826 

3-Methylpentane 0.908 0.524 0.590 

n-Hexane 2.204 1.271 1.431 

2,2,4-Trimethylpentane 0.387 0.296 0.317 

Benzene 0.085 0.044 0.038 

Toluene 0.148 0.091 0.078 

Ethylbenzene 0.060 0.043 0.037 

m-Xylene 0.058 0.041 0.036 

p-Xylene 0.298 0.212 0.183 

o-Xylene 0.117 0.083 0.072 • 

API GRAVITY AT 60/60 F, calculated........................................................................ 57.8 


SPECIFIC GRAVITY AT 60/60 F. calculated .............................................................. 0.7475 


RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.8050 


AVERAGE MOLECULAR WEIGHT .......................................................................... 149.417 


AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 241.399 


TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated ................................................ 46.319 


AVERAGE BOILING POINT, F ................................................................................. 314.836 


CUBIC FEET OF GAS I GALLON OF LIQUID. as Ideal Gas .......................................... 18.857 


BTU I GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 122700.693 


LBS I GALLON OF LIQUID. calculated ...................................................................... 6.232 


,()') \TI( l" '.II (A!(tL\Tl(),,\~ PERF(lR~IE[) ISI1'.G PHYSIC ~I (O"-,S1 \,,\E FRu,1 CP\ 214; 09. nu" nBLES 

01' PHY~I( .\1. C(j"~T \!':TS FOR H'I1)RO( \RB( l,\S \,\1) ( lTHER U lMPUI",ns 01 !};TI-.RESl • 

• 
• 


EXTENDED HYDROCARBON LIQUID STUDIES 

CERTIFlC,\TF ( H .\~,\LYSIS 

Company................ ZENERGY 

Lab Number............. CR·I0330 Study Number............ CR-3B 

Date Sampled ............. 7-15-2010 Date Tested.............. 7-22·2010 

Sample Identification ......•...•..•.. PATRICIA CHARGING 4-15 H CRUDE OIL 

Sample Location ......... MONTANA. 

• 

Sample Pressure .......... N/A Sample Temperature •... N/A 

Flowrate ....•.........••... N/A County.................... . DUNN 

I-QUART 

Test Method.............. VARIOUS 	 Sample Container ........ BOTI1.E 


TEST PERFORMED 

API GRAVITY AT 60/60 F (ASTM D-287), observed ...................... 


SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated .......... 


REID VAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 


TOTAL SULFUR CONTENT (ASTM D-5453), PPMW .................. 


TRUE VAPOR PRESSURE (ASTM D.2889), PSIA AT 100 F ........... 


BASIC SEDIMENT AND WATER CONTENT, % BY VOLUME.... 


COPPER STRIP CORROSION (ASTM D-130), 1 HOUR AT 100 F........... 


FREE WATER, observed ......................................................... 


• NOTATION 

RESULTS 

41.2 

0.8193 

6.6 PSIG 

940.25 	 PPMW 

N/A 

N/A 

N/A 

N/A 

AU TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY 


OLTLINED BY THE AMERICAN SOCIETI FOR TESTING A.'·m MATERIALS (ASTM) 


• 

u.....--3.6351 

-------5.9491 

----------------7_0841 

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

"...,.....---------- 9_7251 

;,;.;,....:..;,.--------10.9131 

-------­

------13.0881 

-_H1I1H--14.0911 

15.950 Io-tetphenyl 

laboralof) , (;;as l'tu.wrcmtl1l 

[ml.jOlon! 1"",lIl1g • Samplt CoU~lIofl • 

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

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

2-6671 

----------~------4_0701 

=;.;>..:WJ..!.....------_______5.610 1Decane (C10) 

• 

12.0311 

• 

5' 

• 

3 
• 


ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS 


• 


• 


Dakota·3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• • • 

Averaae Mandaree Area Gas Compositional Data 

CO2 

(Wt'JlI 

44.010 

1.161 

0.836 

0.n4 

0.87 

0.893 

0.873 

0.681 

0.863 1 

NIIrot"n 

IWt"I 

28.013 

3.626 

2.541 

1.414 

1.352 

3.545 

3.471 

0.471 

HlS 

(Mol""! 

34.081 

0 

0 

0 

0 

0 

a 

0 

C1 


IWt"I 


16.043 

36.543 

33.17 

20.353 

19.208 

25.407 

32.094 

13.456 

C2 

IWt"I 

30.069 

24.689 

23.484 

26.461 

21.796 

22.578 

16.795 

30.949 

C3 

(Wt'JlI 

44.096 

18.317 

18.569 

28.74 

27.321 

25.451 

17.765 

33.204 

2.346 1 0.000 1 25.747 1 23.822 1 24.19S 1 

1.(4 

(Wt'JlI 

58.122 

1.949 

2.543 

3.763 

4.559 

3.399 

3.156 

3.787 

n.(4 

IWt'JlI 

58.122 

5.713 

7.S23 

10.995 

14.169 

11.195 

11.786 

11.001 

3.308 1 10.340 1 

Note: All calculations were pr.formed by Precision Analysis using physical constants from GPA-2145-09. 

1,(5

1-' 

72.149 

1.092 

2.219 

1.776 

2.623 

2.037 

2.666 

1.714 

2.018 

Collected 1011112011 

n-CS 

IWt"I 

72.149 

1.759 

3.884 

2.491 

3.749 

2.674 

3.871 

2.273 

2.957 

C6 

I-I 

86.180 

1.627 

2.219 

1.15a 

1.845 

0.515 

2.76 

0.941 

1.5S1 

C7 


I-I 


101.21 

1.321 

1.481 

0.773 

1.209 

0.789 

2.453 

0.252 

1.183 1 

ClI+ 

IWt"I 

114.23 

0.545 

0.166 

0.498 

0.121 

0.487 

0.109 

0.605 

0.362 

_" Toluene (WI", 

92.140 

0.264 

0.11 

0.216 

0.097 

0.137 

0.215 

0.19 

0.176 

(....n...n.. 

IWI'" 

106.170 

0.014 

0.006 

0.014 

0.007 

0.016 

0.01 

0.011 

0.011 

• 


Xylenes 

IWt"I 

106.160 

0.462 

0.026 

0.05 

0.021 

0.066 

0.038 

0.049 

0.102 

n-tIe.... 

(_I 

86.180 

0.657 

1.138 

0.536 

0.975 

0.771 

1.405 

0.375 

0.837 

me~ 1---1·pemK II..... Gr••1ty IMo"'cuia A".

(8tu'ocll eo_lOll W....t 

1462.236 0.8862 25.666 

1558.1 0.9345 27.065 

1796.8 1.0738 31.101 

1874.17 1.1253 32.591 

1663.5 1.0141 29.37 

1602.8 0.9765 28.281 

1945.1 1.1551 33.454 

Aver,ages I 

(Wt'JI) 

78.112 

0.257 

0.085 

0.038 

0.075 

0.04 

0.53 

0.043 

0.153 

pentane 

114.230 


0.004 


0 


0 


0.002 


0 


0.002 


0 


0.001 11700.3871 1.024 129.64686 

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

29 Country Acre. Rd, RJyerton. WY 82501 

ontlno, _.Proct.ton-Lllb•.com 

PRE~ E_alb Infoll!Pr.cl.t..,....b•.com

~AN SIS Toll f'r_ ....mben (1158, "1~18.

Client: SISON ENGINEERING Analysis Date: 10/11/2011 

Sample 10: AUSIA FOX 16-9 Date Sampled: 10/11/2011 

Unique #: Purpose: 

Sample Temperature: 62 DEG F Sample Pressure: 20 PSI 

•

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

Components 

Carbon Dioxide .........•... 

Mole % 

0.677 

Weight 0/0 

1.161 

Liq. Vol. % 

0.551 

Hydrogen Sulfide ........... 

Nitrogen ...................... 

Methane ...................... 

0.000 

3.323 

58.464 

0.000 

3.626 

36.543 

0.000 

1.742 

47.240 

Ethane ........................ 

Propane ....................... 

iso-Butane ................... 

n-Butane ...................... 

21.074 

10.662 

0.861 

2.523 

24.689 

18.317 

1.949 

5.713 

26.862 

13.999 

1.342 

3.791 

iso-Pentane .................. 0.389 1.092 0.677 

n-Pentane .................... 

Cyclopentane ............... 

n·Hexane ..................... 

0.599 

0.028 

0.196 

1.684 

0.075 

0.657 

1.035 

0.039 

0.384 

Cyclohexane ................ 

Other Hexanes ............. 

0.196 

0.147 

0.642 

0.492 

0.317 

0.287 

Heptanes ..................... " 

Methylcyclohexane ........ 

2,2,4-Trimethylpentane ... 

Benzene ...................... 

Toluene ....................... 

0.338 

0.129 

0.001 

0.085 

0.073 

1.321 

0.493 

0.004 

0.257 

0.264 

0.744 

0.247 

0.002 

0.113 

0.117 

Ethylbenzene ............... 

Xylenes ....................... 

C8+ Heavies ................ 

0.003 

0.112 

0.122 

0.014 

0.462 

0.545 

0.006 

0.206 

0.299 

Totals ........................ 100.000 100.000 100.000 

• 
• 


ADDITIONAL BETX DATA 


Components Mole % Weight % Liq. Vol. % 


Cydopentane 

Cyclohexane 

2-Methylpentane 

3-Methylpentane 

n-Hexane 

Methylcyclohexane 

2,2,4-Trimethylpentane 

Benzene 

Toluene 

• 

Ethylbenzene 

m-Xylene 

p-Xylene 

o-Xylene 

0.028 0.075 0.039 

0.196 0.642 0.317 

0.092 0.310 0.181 

0.054 0.182 0.106 

0.196 0.657 0.384 

0.129 0.493 0.247 

0.001 0.004 0.002 

0.085 0.257 0.113 

0.073 0.264 0.117 

0.003 0.014 0.006 

0.018 0.073 0.033 

0.076 0.313 0.139 

0.018 0.076 0.034 

SPECIFIC GRAVITY@60/60 F. calculated ................................................... 0.8862 


TOTAL GPM (Ethane Inclusive) ................................................................. 10.561 


CALCULATED BTU I REAL CF @ 14.73 PSIA, dry basis.................................. 1462.236 


CALCULATED BTU I REALCF@14.73PSIA,wetbasis.................................. 1437.527 


AVERAGE MOLECULAR WEIGHT........................................................... . 25.666 


MOLAR MASS RATIO.. ,........................................................................... 0.8862 


RELATIVE DENSITY ( G :II: Z (Air) I Z ). calculated........................................ 0.8911 


IDEAL GROSS HEATING VALUE, BTU I IDEAL CF @ 14.696 PSIA.................. 1450.907 


COMPRESSIBIUTY FACTOR (Z).............................................................. 0.99453 


PROPANEGPM ..................................................................................... 2.9297 


BUTANEGPM ....................................................................................... 1.0743 


GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 0.9357 


~(n \TI<II.I ( \I.U I. \T1(l~S PERrOR"IED I ~I:--(' PHY,I( II « )',ST\~T~ I'R( )\1 (,1'\ 211i II') fHI I ".Ill.F, 

• Ilf PHYSIC \1 (O:-':ST,0:TS FOR HYDRo( \lUl()"," \~D()TH!)RC')\IP()I~[)S('I L"-TLRL,'j 

n) rHF " \ n R,I!. G \5 I:-JDI ,TRy 

• 

• 

29 Country Acres Rd, Riverton, WY 82501 

Online: _.Preclslon-La.s.com 

E-mail: Infot\.Pr_lslon.Laba.com 

Toll Fro. Number. (888) 985.080 

Client: BISON ENGINEERING Analysis Date: 10/11/2011 

Sample 10: HIGH HAWK 4-9 Date Sampled: 10/11/2011 

Unique #: Purpose: 

Sample Temperature: 59 DEG F Sample Pressure: 25 PSI 

•

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

Components Mole % Weight % Liq. Vol. % 


Carbon Dioxide ............. 0.517 0.681 0.356 


Hydrogen Sulfide ........... 0.000 0.000 0.000 


Nitrogen ...................... 0.562 0.471 0.249 


Methane ...................... 28.060 13.456 19.176 


Ethane ........................ 34.433 30.949 37.122 


Propane ....................... 25.191 33.204 27.977 


iso-Butane ...... , ............ 2.180 3.787 2.875 


n-Butane ...................... 6.332 11.001 8.047 


iso-Pentane .................. 0.795 1.714 1.172 


n-Pentane .................... 1.017 2.194 1.487 


Cyclopentane ............... 0.037 0.079 0.045 


n-Hexane ..................... 0.146 0.375 0.242 


Cyclohexane.., ............. 0.047 0.119 0.065 


Other Hexanes ............. 0.291 0.749 0.482 
 .. 

Heptanes ..................... 0.084 0.252 0.157 


Methylcydohexane ........ 0.025 0.073 0.040 


2,2,4-Trimethylpentane... 0.000 0.000 0.000 

Benzene ...................... 0.D18 0.043 0.021 


Toluene ....................... 0.069 0.190 0.093 


Ethylbenzene ............... 0.004 0.011 0.005 


Xylenes ....................... 0.015 0.049 0.024 


C8+ Heavies ................ 0.177 0.605 0.366 


Totals ........................ 100.000 100.000 100.000 


• 
• 


• 


• 


ADDITIONAL BETX DATA 


Components Mole % Weight % Liq. Vol. % 


Cyclopentane 

Cyclohexane 

2-Methylpentane 

3-Methylpentane 

n-Hexane 

Methylcyclohexane 

2,2.4-Trimethylpentane 

Benzene 

Toluene 

Ethylbenzene 

m-Xylene 

p-Xylene 

o-Xylene 

0.037 0.079 0.045 

0.047 0.119 0.065 

0.183 0.471 0.303 

0.108 0.278 0.179 

0.146 0.375 0.242 

0.025 0.073 0.040 

0.000 0.000 0.000 

0.018 0.043 0.021 

0.069 0.190 0.093 

0.004 0.011 0.005 

0.002 0.008 0.004 

0.010 0.033 0.016 

0.003 0.008 0.004 

SPECIFIC GRAVITY@ 60/60 F, calculated ................................................. .. 1.1551 


TOTAL GPM (Ethane Inclusive) ................................................................. 19.847 


CALCULATED BTU I REAL CF @ 14.73 PSIA,. dry basis .................................. 1945.085 


CALCULATED BTU I REAL CF@ 14.73 PSIA, wet basis.................................. 1911.926 


AVERAGE MOLECULAR WEIGHT............................................................ 33.454 


MOLAR MASS RATIO.............................................................................. 1.1551 


RELATIVE DENSITY ( G x Z (Air) I Z ), calculated ........................................ 1.1668 


IDEAL GROSS HEATING VALUE, BTU I IDEAL CF @ 14.696 PSIA ................ .. 1921.067 


COMPRESSIBIUTY FACTOR (Z) .............................................................. 0.98992 


PROPANE GPM ..................................................................................... 6.9222 


BUTANEGPM ...................................................................................... . 2.7025 


GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 1.0377 


'«IT\TH)" IlJ (\!.u IlnO'SPfRH'R,IFDLSL,CI'HYSICli U)";T\.'TSrR{)'!CP\21~'il\'. [HI [\[ILlS 

(If' PH) ,I( II C()~.sl ,"T~ H lR HYDRO( .\RB( )", ,,'<D OTHFR u ),[POI "!l:; (Ie l'dfR[ ')T 

ro nil" Y[{ R.\' (, I' I"DL ,TR\ 

• 

• 

29 Countrll Acre, Rd, Riverton. WY 82501 PRECISION/7 Online. _.Precl.lon·Lab••com

E-mall.lnfoGlP.ecl.lon·Lab••com 

~SiS Toll Free Numb.... (866) '85-G8&6

Client: BISON ENGINEERING Analysis Date: 10/11/2011 

WILLIAMS 

Sample 10: NATHAN HALE 3-18 Date Sampled: 10/11/2011 

Unique": Purpose: 

Sample Temperature: 59 DEG F Sample Pressure: 15 PSI 

•

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

Components Mole % 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane ....................... 


iso-Butane ................... 


n-Butane ...................... 


iso-Pentane .................. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................... 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane ... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xytenes ....................... 


(8+ Heavies ................ 


Totals ........................ 


0.561 

0.000 

3.504 

56.578 

1S.797 

11.394 

1.536 

5.735 

1.045 

1.419 

0.102 

0.461 

0.304 

0.333 

0.692 

0.242 

0.001 

0.192 

0.066 

0.003 

0.010 

0.027 

100.000 

Weight % 

0.873 

0.000 

3.471 

32.094 

16.795 

17.765 

3.156 

11.786 

2.666 

3.619 

0.252 

1.405 

0.903 

1.015 

2.453 

0.842 

0.002 

0.530 

0.215 

0.010 

0.038 

0.109 

100.000 

Liq. Vol. % 

0.443 

0.000 

1.784 

44.375 

19.545 

14.522 

2.325 

8.364 

1.768 

2.379 

0.139 

0.877 

0.478 

0.634 ..

1.478 

0.451 

0.001 

0.248 

0.102 

0.005 


0,018 


0.064 

100.000 

• 
• 


ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

Cyclopentane 0.102 0.252 0.139 

Cyclohexane 0.304 0.903 0.478 

2-Methylpentane 0.210 0.639 0.399 

3-Methylpentane 0.123 0.376 0.235 

• 

n-Hexane 0.461 1.405 0.877 

Methylcyclohexane 0.242 0.842 0.451 

2,2,4-Trimethylpentane 0.001 0.002 0.001 

Benzene 0.192 0.530 0.248 

Toluene 0.066 0.215 0.102 

Ethylbenzene 0.003 0.010 0.005 

m-Xylene 0.002 0.006 0.003 

p-Xylene 0.007 0.026 0.012 

o-Xylene 0.002 0.006 0.003 

SPECIFIC GRAVITY @60/60 F, calculated ................................................... 0.9765 


TOTAL GPM (Ethane Inclusive) ................................................................. 11.511 


CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis.................................. 1602.761 


CALCULATED BTU / REAL CF@14.73 PSIA, wet basis .................................. 1575.593 


AVERAGE MOLECULAR WEIGHT.......................................................... .. 28.281 


MOLAR MASS RATIO............................................................................. . 0.9765 


RELATIVE DENSIlY ( G x Z (Air) / Z ), calculated ........................................ 0.9832 


IDEAL GROSS HEATING VALUE, BTU / IDEAL CF @ 14.696 PSIA .................. 1588.143 


COMPRESSIBIUlY FACTOR (Z).............................................................. 0.99316 


PROPANE GPM ..................................................................................... 3.1309 


BUTANEGPM ..................................................................................... .. 2.3045 


GASOUNE GPM (PENTANE AND MEAVIER) ........................................... 1.8621 


• 
 '" nnl<)'. 'ILl C'ILCUHH )'" PERH lR.\!ED L SI'.(; PHYSIC \1 , ().',:i·1 \;>-.. r.s FR( )\1 (;1'\ "·Ii ,,'J ['HI- I \[JLr~ 

(Jr I'HYSJ( .\1 (()'.~1 v,:rs H)R HYDR')( \RU( '" -'1'-1) ()THI-R ( U\!l'()1 'J), (n I:o..n- Rfsr 

fO fHE '- \TYR.\l C \~ I0:Dl STRY 

• 

• 

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

E-mail: In.o(!IPreclalon·Lab••com 

~SYs Toll Free Number. (8&&) 985-08&&

Client: BISON ENGINEERING Analysis Date: 10/11/2011 

WILLIAMS 

Sample 10: SKUNK CREEK 1-12 Date Sampled: 10/11/2011 

Unique If: Purpose: 

Sample Temperature: 78 DEG F Sample Pressure: 30PSJ 

•

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

Components Mole % 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane ....................... 


iso-Butane ................... 


n-Butane ...................... 


iso-Pentane... , .............. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................... 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane ... 


Benzene ........ , ............. 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.596 

0.000 

3.717 

46.514 

22.053 

16.952 

1.718 

5.657 

0.829 

1.021 

0.070 

0.263 

0.077 

0.061 

0.231 

0.034 

0.000 

0.015 

0.044 

0.004 

0.018 

0.125 

100.000 

Weight % 

0.893 

0.000 

3.545 

25.407 

22.578 

25.451 

3.399 

11.195 

2.037 

2.507 

0.167 

0.771 

0.222 

0.178 

0.789 

0.115 

0.000 

0.040 

0.137 

0.016 

0.066 

0.487 

100.000 

Liq. Vol. % 

0.454 

0.000 

1.828 

35.242 

26.359 

20.872 

2.512 

7.971 

1.355 

1.654 

0.092 

0.483 

0.118 

0.112 ..

0.477 

0.062 

0.000 

0.019 

0.065 

0.008 

0.032 

0.287 

100.000 

• 
• 


ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

• 

Cydopentane 0.070 0.167 0.092 

Cydohexane 0.077 0.222 0.118 

2-Melhylpentane 0.038 0.112 0.070 

3-Methylpentane 0.023 0.066 0.041 

n-Hexane 0.263 0.771 0.483 

Methylcyclohexane 0.034 0.115 0.062 

2,2,4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.Q15 0.040 0.019 

Toluene 0.044 0.137 0.065 

Ethylbenzene 0.004 0.016 0.008 

m-Xylene 0.003 0.011 0.005 

p-Xylene 0.012 0.045 0.021 

o-Xylene 0.003 0.011 0.005 

SPECIFIC GRAVITY@60/60 F, calculated................................................... 1.0141 


TOTAL GPM (Ethane Inclusive)................................................................. 13.943 


CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis .................................. 1663.548 


CALCULATED BTU / 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) / Z ). calculated........................................ 1.0215 


IDEAL GROSS HEATING VALUE, BTU / 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 


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

• 

• 

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

1!_.lb InfoCllPreclalon.Labs.cem 

~SfS Toll Fr•• Humbert (8&81 985-0866

Client: BISON ENGINEERING Analysis Date: 10/11/2011 

WILLIAMS 

Sample 10: TAT 2-1 Date Sampled: 10/11/2011 

Unique #: Purpose: 

Sample Temperature: 117 DEG F Sample Pressure: 17 PSI 

•

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

Components Mole%. 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane ...................... 


Ethane ........................ 


Propane ....................... 


isO-Butane ................... 


n-Butane ...................... 


iso-Pentane .................. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................... 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane ... 


Benzene ...................... 


Toluene ....................... 


Ethyl benzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.644 

0.000 

1.573 

39.023 

23.624 

20.193 

2.557 

7.945 

1.185 

1.596 

0.101 

0.369 

0.172 

0.417 

0.393 

0.099 

0.001 

0.031 

0.034 

0.002 

0.007 

0.035 

100.000 

Weight%. 

0.870 

0.000 

1.352 

19.208 

21.796 

27.321 

4.559 

14.169 

2.623 

3.532 

0.217 

0.975 

0.445 

1.101 

1.209 

0.299 

0.002 

0.075 

0.097 

0.007 

0.021 

0.121 

100.000 

Liq. Vol. % 

0.462 

0.000 

0.727 

27.788 

26.538 

23.368 

3.514 

10.521 

1.820 

2.430 

0.125 

0.637 

0.246 

0.720 

0.762 

0.168 

0.001 

0.037 

0.048 

0.004 

0.011 

0.074 

100.000 

" 

• 
• 


ADDITIONAL BETX DATA 

• 

Components Mole % Weight % Liq. Vol. % 

Cyclopentane 0.101 0.217 0.125 

Cyclohexane 0.172 0.445 0.246 

2-Methylpentane 0.262 0.693 0.453 

3-Methylpentane 0.154 OA08 0.267 

n-Hexane 0.369 0.975 0.637 

Methylcyclohexane 0.099 0.299 0.168 

2.2,4-Trimethylpentane 0.001 0.002 0.001 

Benzene 0.031 0.075 0.037 

Toluene 0.034 0.097 0.048 

Ethylbenzene 0.002 0.007 0.004 

m-Xylene 0.001 0.003 0.002 

p-Xylene 0.004 0.014 0.007 

o-Xylene 0.001 0.003 0.002 

SPECIFIC GRAVITY@6O/6O F, calculated ................................................... 1.1253 


TOTALGPM (Ethane Inclusive) ................................................................. 16.864 


CALCULATED BTU / 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 


• 


N{)TITj()" ~I.[ (1I.U!.\Tj(''':)PFRH)I(~IU)lSI''CPH1~1( \1 Ul"-'STI',bl I((l\! (.1'1 'I~~",l) rH! LIBLr, 


Or PHYSIC\I (( )"'iT''']''; r' >1( H,DR( J( IRI.\(>"5 1"1) \ n HU, ( ('\II'! J1 \'1l5! )1' I;-';TfRLSl 

• 

• 

29 Country Acres Rei. Riverton, WY 82501 PRECISION7 Online, _.Preclslon-LIdos.cDm

e......111 '"foCP_tsIOft·Labs.cDm 

~SfS Toll Free Number. (8.&) 985-0866

Client: BISON ENGINEERING Analysis Date: 10/11/2011 

WILLIAMS 

Sample 10: WELL 32-29 Date Sampled: 10/11/2011 

Unique#: Purpose: 

Sample Temperature: 66 DEG F Sample Pressure: 20 PSI 

•

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

Components Mote % 

Carbon Dioxide ............. 


Hydrogen Sulfjde .....•..... 


Nitrogen ...................... 


Methane ...................... 


Ethane ......................... 


Propane ....................... 


iso-Butane ................... 


n-Butane ...................... 


iso-Pentane..., .............. 


n-Pentane .................... 


Cyc!opentane ............... 


n-Hexane ..................... 


Cyc!ohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........................ 


0.512 

0.000 

1.570 

39.457 

27.369 

20.271 

2.013 

5.884 

0.765 

1.021 

0.054 

0.193 

0.066 

0.261 

0.240 

0.081 

0.000 

0.015 

0.073 

0.004 

0.Q15 

0.136 

100.000 

Weight % 

0.724 

0.000 

1.414 

20.353 

26.461 

28.740 

3.763 

10.995 

1.776 

2.368 

0.123 

0.536 

0.180 

0.724 

0.773 

0.254 

0.000 

0.038 

0.216 

0.014 

0.050 

0.498 

100.000 

Liq. Vol. % 

0.372 

0.000 

0.735 

28.475 

31.158 

23.773 

2.805 

7.896 

1.192 

1.575 

0.069 

0.339 

0.096 

0.457 

0.471 

0.138 

0.000 

0.018 

0.104 

0.007 

0.024 

0.296 

100.000 

• 

• 
• 


• 


• 


ADDITIONAL BETX DATA 

Components Mole &/0 Wei~ht % Liq. Vol. % 

Cyclopentane 0.054 0.123 0.069 

Cyclohexane 0.066 0.180 0.096 

2-Methylpentane 0.164 0.455 0.288 

3-Methylpentane 0.097 0.268 0.169 

n-Hexane 0.193 0.536 0.339 

Methylcyclohexane 0.081 0.254 0.138 

2,2,4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.015 0.038 0.018 

Toluene 0.073 0.216 0.104 

Ethylbenzene 0.004 0.014 0.007 

m-Xylene 0.002 0.008 0.004 

p-Xylene 0.010 0.034 0.016 

o-Xylene 0.002 0.008 0.004 

SPECIFIC GRAVITY @ 60/60 F, calculated ................................................... 1.0738 

TOTAL GPM (Ethane Inclusive) ................................................................. 16.499 

CALCULATED BTU 1REAL CF @ 14.73 PSIA, dry basis.................................. 1796.792 

CALCULATED BTU 1 REAL CF @ 14.73 PSIA, wet basis .................................. 1766.229 

AVERAGE MOLECULAR WEIGHT............................................................ 31.101 

MOLAR MASS RATIO.............................................................................. 1.0738 

RELATIVE DENSITY ( G x Z (Air) 1 Z ), calculated ........................................ 1,0830 

IDEAL GROSS HEATING VALUE. BTU 1IDEAL CF @ 14.696 PSIA .................. 1777.412 

COMPRESSIBIUTY FACTOR (Z).............................................................. 0.99149 

PROPANE GPM ..................................................................................... 5.5702 

BUTANEGPM ....................................................................................... 2.5073 

GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 1.1204 

;-..:(n IrH'~ II[ (ILU[ ·In(l·,.'jlFI\H'R\[F.lllSl~(,PH)S/( ,I \()~:;T\~r.i"R(;\I(;P\ :1)'''''. nil lllll[ 

; 'i" PHY,[( ,I (( ,'\,ST 'I" rs f( lR IlYDR()( '1Rlll)\.;; ·1'1) [lTHFR ( ( j\[P( H 'I), '[ I"TI' RISl 

n, fill '0. HI 1\.11 C, I> I~m )1'R, 

• 

• 

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

E_III InfofllPreclslon.Labs.com 

~SfS Toll Free Numbert (8661 985-0866

dient: BISON ENGINEERING Analysis Date: 10/11/2011 

WILLIAMS 

Sample ID: WOLF 27-34 Date Sampled: 10/11/2011 

Unique #: Purpose: 

• 

Sample Temperature: 60 DEG F Sample Pressure: 30 PSI 

Sampled By: TC Type Sample: ONLINE 

County: DUNN 

• 

• 

Components Mole % 

Carbon Dioxide ............. 


Hydrogen Sulfide ........... 


Nitrogen ...................... 


Methane...................... 


Ethane ........................ 


Propane ....................... 


iso-Butane ................... 


n-Butane ...................... 


iso-Pentane .................. 


n-Pentane .................... 


Cyclopentane ............... 


n-Hexane ..................... 


Cyclohexane ................ 


Other Hexanes ............. 


Heptanes ..................... 


Methylcyclohexane ........ 


2,2,4-Trimethylpentane ... 


Benzene ...................... 


Toluene ....................... 


Ethylbenzene ............... 


Xylenes ....................... 


C8+ Heavies ................ 


Totals ........... " ........... 


0.514 

0.000 

2.455 

55.961 

21.138 

11.397 

1.184 

3.503 

0.833 

1.363 

0.097 

0.357 

0.150 

0.456 

0.400 

0.082 

0.000 

0.030 

0.032 

0.002 

0.007 

0.039 

100.000 

Weight % 

0.836 

0.000 

2.541 

33.170 

23.484 

18.569 

2.543 

7.523 

2.219 

3.634 

0.250 

1.138 

0.467 

1.453 

1.481 

0.299 

0.000 

0.085 

0.110 

0.006 

0.026 

0.166 

100.000 

Liq. Vol. % 

0.406 

0.000 

1.250 

43.916 

26.169 

14.535 

1.794 

5.113 

1.409 

2.287 

0.132 

0.680 

0.236 

0.868 

0.854 

0.153 

0.000 

0.038 

0.050 

0.003 

0.012 

0.093 

100.000 
• 


ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

Cyclopentane 0.097 0.250 0.132 

Cyclohexane 0.150 0.467 0.236 

2-Methylpentane 0.287 0.914 0.547 

3-Methylpentane 0.169 0.538 0.322 

n-Hexane 0.357 1.138 0.680 

Methylcyclohexane 0.082 0.299 0.153 

2,2,4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.030 0.085 0.038 

Toluene 0.032 0.110 0.050 

Ethylbenzene 0.002 0.006 0.003

• m-Xylene 0.001 0.004 0.002 

p-Xylene 0.005 0.018 0.008 

o-Xylene 0.001 0.004 0.002 

SPECIFIC GRAVITY @60/60 F, calculated................................................... 0.9345 


TOTAL GPM (Ethane Inclusive) ................................................................. 11.726 


CALCULATED BTU / REAL CF @ 14.73 PSlA, dry basis.................................. 1558.098 


CALCULATED BTU / REAL CF @ 14.73 PSlA, wet basis .................................. 1531.712 


AVERAGE 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 @ 14.696 PSIA.................. 1544.831 


COMPRESSIBILITY FACTOR (Z).............................................................. 0.99377 


PROPANE GPM ................................................................................... .. 3.1318 


BUTANEGPM ..................................................................................... .. 1.4882 


GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 1.4675 


\;( n\TI()" \U (\U l. I. Hlu,," PIRFClR\lrn ! 'i1'.C, PHYSIC \1 (O'.;S1 ,,,T'i I'R( )\1 (;1' \ ,11i ",y' I Hr I \lll.f' 

• 01 PH) 'il( \1 ( (I",T '" r'i f'()R H~ OR( Ie \RB()'.~ ,'.1) (ITHf'R < ( )\11'< II .,;n:; (II I, rr H' I 

f(l rHr ,UI R \J \'i l\;lll:iTIn 

• 

• 


ATTACHMENT F: ENGINE MANUFACTURER'S SPECS 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
This section 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..lTERPILLARe 

• 

FEATURES 

EMISSIONS 

• 	EPA Tier 3 and CARB Emissions Certified for 

non-road mobile applications at all 60 Hz and 

50 Hz ratings 

CAT C9 ATAAC DIESEL ENGINE 

e Utilizes ACERT- Technology 

• Reliable, rugged, durable design 

• Field-proven in multiple applications 

worldwide 

• Four-stroke-cycle diesel engine combines 

durability with minimum weight while 

providing dependability and economy 

• 	50/60 Hz convertibility 

CAT SR4B GENERATOR 

• Designed to match performance and output 

characteristics of diesel engines 

e Permanent magnet excitation 

• 

• Segregated AC/DC, low voltage accessory box 

provides single point access to accessory 

connections 

ENCLOSURE 

• Made with 12-gauge steel 

• Single point lifting eye 

• Sou nd attenuated 

• Convenient hand holds and steps for safe 

operation 

• Two coat polyester powder-coated finish 

Arrangement shown 

with optional trailer 

XQ230 

SOUND ATTENUATED 


DUAL VOLTAGE 

50/60 Hz 

ENVIRONMENTALLY FRIENDLY DESIGN 

• Sound attenuated for low noise operation 

• OSHA compliant safe design 

• 	110% spill containment for coolant and oil 

• UL142 certified dual wall fuel tank 

MULTI-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 SUPPLIER 

• Complete systems designed at Caterpillar 

ISO 9001 :2000 certified facilities 

• CertHied Prototype Tested with torsional 

analysis 

WORLDWIDE PRODUCT SUPPORT 

• 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.l.TERPILLAR­

• 

STANDARD FEATURES 

Air Inlet System Air cleaner, dua' element 

Turbocharger 

Charging System Battery charger 

Heavy duty charging alternator 

Control Panel Generator controls and monitoring 

Fuel tank monitoring 

Engine controls and monitoring 

Digita' displays 

Cooling System Fan and belt guards 

Base mounted radiator 

Air to air afteroooling 

Distribution Panel lockable doors 

load door safety switch, (trips breaker 

upon door opening) 

Individual bus bar connections 

Circuit breaker with 24 VDC shunt trip 

Remote start/stop contacts 

Shore power connections 

Enclosure Sound attenuated 

12-9auge stael 

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 fllter/water seperator 

UL142 dIJal wall fuel tank 1667 L (440 gall 

Radiator-mountad fuel cooler 

Genet'ator Brushlass, permanent magnet 

Coastal corrosion protection 

Shock mounted VR6 voltage regulator 

Space heater 

ULapproved 

Simultaneous three-phase 4801277 and 

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 EOUIPMENT 

OPTIONAL FEATURES 

Trailer Full frame support 

Independent tandem axle trailer frame 

with tongue 

Electric actuatad hydraulic brakes 

with rechargeable battery backup 

breakaway system. 

Overcenter mechanical parking brake 

Full length fenders 

Non-skid surface on steps 

Heavy duty safety 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 brushless 

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•..•...••...•..•... :1: %% steady state/:I: %% 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 (4.41) 

Stroke - mm (in) ................................ 149 (5.B7) 

Displacement - L (cu in)........... " ....••......•• B.B (537) 

Compression ratio ................................... 16.1:1 

Aspiration••••••.••....•.... Turbocharged AA charge cooled 

Engine control ••••••••....••...•.•.•..••..•.•.• ADEMTM A4 

CAT CONTROL PANEL - EMCP 3.2 

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 yoltages. 

X0230 

Power Rating 

60Hz 

50Hz 

ekYV 

INA 

StandbY TMlRef. PrIme 1M..... 

230 DM8S02 210 DM8512 

275 DM85CM 

Engine and Container lnformll1ion 

Engine model 

Container dimensions 

C9 see chart onjlage 6 

ShIppIng WeIght IDry) 

Unit with trailer kg Ub) 6210 (13,690) 

Unit without trailer 

Maximum Fuel Capacity Weight 

kg IIbl 4960 (10,980) 

Unit with trailer kg UbI 7506 (16,5501 

Unit without trailer kg Ubi 6278 (13.8401 

Engine Lubrfc:atlng Oil Capacity 

Engine Coolant Capacity with Radiator 

Fuel Tank Capacity 

L(gall 

L(gall 

L (gal) 

40 (10.551 

36(9.61 

1516 (400) 

Fuel Consumption lIhr (gaVl'lr) 69.2 418.3) 64.7 (17.1) 

Fuel Consumption (75% Prime) lIhr fgaVl'lr) 50.6 (13.4) 

Running Tune @ 75% Prime 

Sound Level 

hours 28 

Standby dB(A) 74.72 

No load @ 7 m (23 tt) dB(A) 70.20 

Prime dB(A) 73.49 

Ambient Capability Deg C (De9 F) 43 (109.4) 

lEHE5329-03 3 

• 

•

RENTAL 	 C.ATERPILLARRATING DEFINITIONS AND CONDITIONS 

Meets or Exceeds International Specifications: 

• 	NEMA MG1-32, IEC 60034, CSA, 98/37/EEC, 72123/EEC, 

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

Standby - Output available with varying load for the 

duration of the interruption of the normal source power. 

Standby power in accordance with IS08528. Fuel stop power 

in accordance with IS03046/1, AS2789, DIN6271, and B55614. 

Prime - Output available with varying load for an unlimited 

time. Prime power in accordance with IS08528. 10% overload 

power in accordance with 1503046/1, AS2789, DIN6271, and 

B56514 available on request. 

Ratings are based on 5AE J1349 standard conditions. 

These ratings also apply at 150304611, DIN6271, and B55514 

standard conditions. 

Fuel rates are based on fuel oil of 35° API f@ 16° C (60· F)l 

gravity having an LHV of 42 780 kJ/kg (18,390 Bt\.lllb) when used 

at 29° C (85· Fl and weighing 838.9 g/liter (7.0011b1U.5. gal). 

Additional ratings may be available for specific customer 

requirements. Consult your Caterpillar representative for details. 

• 

• 

lEHE5329-03 	 4 

• 
• RENTAL C..lTERPILLARDISTRIBUTION PANEL 


C"TERPILLAR' 

.. ~~. I~)!:II F. . ,,", 

. iii 

•.oco.!!!!.-.. .--... 

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 (Y2-) ground stud 

16. Dual voltage load connection bus board 

[6.35 mm x 101.6 mm x 101.6 mm 

(YIN x 4" x 4M) bus bars1 

• 


lEHE5329·03 5 

• 

• 

RENTAL C.TERPILLARe 

CONTAINER DIMENSIONS - TOP VIEW 


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

r~ 

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

CONTAINER DIMENSIONS - RIGHT SIDE VIEW 

• 

I 

I 

Overall Dimensions 

Package With Trailer I 

Length 4597.4mm 1S1in 6248.3mm 246 in I 

Width 1498.6mm 69 In 2540.0mm 100 In I 

Height 2387.6mm 94 In 2882.8 tnm 113.5 in 

.. 

LEHE5329·03 6 

• 
• 


ATTACHMENT G: EMISSION CONTROL DEVICE 

MANUFACTURER'S SPECS 

• 


• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


C""'N CIMARRON ENERGV INC. 

EMISSION CONTROL DEVICES (ECD) 

• 

Cimarron Energy Tank VOC 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 VOC 

emissions from the Oil/Condensate Production Tanks with clean efficient 

destruction. Cimarron ECDs have been independently tested and certified to 

exceed the strict EPA requirements with a 99% destruction rate. 

Specifications on the next page. 

Auto Ignition systems also available. 

• 

Home Olliee: 10(580) 338·5496 FAX 1·(S60) 338·0885 P.O, Box '405. Guymon, Oklahoma 731W2 


Administrativ.Offiee: 1·(405) 928·7373 FAX 1·(405) '928·7380 P.O. So> 722110. Norman, Oklahoma 73010 


• 

---

I 

! 

\) 

I ~ 

! '0'0 

1\ .1 B r·-I

'

C 

• 

I~"'f~1i 10f--;'\"'- ~J .. _ ------,--- (J S)t; 

• 

W~ 

""~j, 

• • 

w 

48" DlA x 302 sJrr HEIGHT, 88 ORIfICES 

EMISSION <DNTROl DEVICE 

'* >98% lVOC ORE. CERTIfIED USEPA 40 CFR 


00, APPENDIX A, SOURCE EMMISIONS TEST 


METHODS REFERS«:ED. MEETS ALL EPA & 


CDPHE REGULATIONS. 


.. DfSTROYS OIIJCONDENSATE PRODUCTION 


TANK VAPORS WI NO VISIBLE FlAME. 
 .. EXCBJ.fNT 0PA0.n' AND SMOKElESS 


OPW'11ON. 


• RElJABlE AND OJSTOMIZABl£ IGNITION. 

'" veRY LCIN CAPITAL AND OPERATING COST. 

'" EASt TO OPERATE AND MAINTAIN, 

'" WILl DESTROY UP TO 150 MCfD @ 10 WilJ 

""'~' oec: 

A 

SI'£C1fB 

IIISC: 

__M>U calf, 2CIlON \l1li otv, 

__"'_, _II' 

CIMARRON tHIwr ..... 

m~ "ImH\IOi..UMffCO 

<1m; IWI)!,,,,,, I~" "" I 

I 

""--1 

IIA'lI!:­

I 

I

I 

00IlP, 

..:u.s 
i 

• 

ATTACHMENT H: 	 PROCESS FLOW DIAGRAM OF 

FACILITY 

• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324

• 
• 

----------

---

• 

--

• 

-------

Woter 

PlpeDn. OIIP1peU"" 

+-8--~ .......... ----------~ 

!+-~ ~ +-­

-SG'Jl--'.,...---­ Unit 

---- .. 

+-­

>'0:·M",,,,~....,,,,,,,,-~,-",,y·,.,,t!<\,..,..,.,.,,,,,,,J"" "" ·~·--";'>If~~~-~tI,..-_-""r~'''''''''' ____'''''f'''''·,'',""" '-_"'F._~,~.."",":"",__~>_,..._~_~"""""","", ',,....·,...H_~_~__ ,~·~-,·~"""'~'·'''·'·~'''''''''_-''''-rr·''~"_'.'~4>_~0",·"",.~~'t'·h"""""'",.·q\""-.;!i"'0."~'YII1l>'-"-f'''~'-~___ "''1'>"~\'I\'\''('",:,,<~'''''0i''''''''"_~~ __~''''·)iI'¥),"lI"'Nll""'~________' 

TYPICAL MANDAREE AREA 


SIX WELL PAD FACILITY PLOT PLAN 


Dakota-3 E&P Company, LLC 


FBIR, North Dakota 


NOT TO SCALE 


• 

8 GooM""r~... _______ +­

r----­

I Tank VOIIt Un< Goo", ... I 

I 

I 

Combustor 

Enclosed I 

I 

"4 X 2O'h I 

I Valve - ~CI I I'...J -p,---+-: 

I I 

I 1 -~·I 

I 

1 

1 . ., I : 

-_4~-1101 _Met<. 

, I Valve !- --...c::;:::J ., _ J , 

I ' ' 

1 

r .-1 I ' 

-.... ,5>4.: .. I Vain 

.. -.: 1 

I 

. _" I I 

_1_ I I Utility i.. 1 l""'-::1+: Flare _,_.: 

I 

Volve " I 

I I I 

____ J:..'t__ • .. .--11--- -~.." 

I 

I 

'r;.o-...:I :' ------r,~--. ..:. I Vain I, 6'dxxrh ......... .lO"'. I 
 , " .. I : 

------~----- - - ..R.:1"--::I-1I" Legem -.~~--------- '-0-.i-'­ r • I Valve ---01.'" BerlN 


Crude 

Wilier Line 


Line 

~ 

FIowIiDe 

Buried R""",1e Lin.. 


Oaa Sn1e, Line 


Tank Vapor LiM 


PIared Gas Line 

• 

ATTACHMENT I: 	 PRODUCTION DECLINE CURVE 

CALCULATIONS 

• 


• 


Oakota-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 1 of 6 • 

Identification 

User Identification: 

City: 

State: 

Company: 

Type of Tank: 

Description: . 

Tank Dimensions 

Shell Length (It): 

Diameter (It): 

Volume (gallons): 

Turnovers: 

Net Throughput(gal/yr): 

Is Tank Heated (y/n): 

Is Tank Underground (y/n): 

Paint Characteristics 

Shell Color/Shade: 

Shell Condition 

Breather Vent Settings 

Vacuum Settings (psig): 

Pressure Settings (psig) 

TANKS 4.0.9d 


Emissions Report - Detail Format 


Tank Indentification and Physical Characteristics 


1 000 gallon diesel tank 

Williston 

North Dakota 

Williams E&P, LLC 

Horizontal Tank 

1,000 gallon diesel tank to fuel onsite diesel generators. Tank throughput is based on engine fuel consumption. 

10.00 

4.16 


1,000.00 


2,244.31 


2.244,312.00 

N 

N 

Gray/Medium 

Good 

-0.03 

0.03 

Meterological Data used in Emissions Calculations: Bismarck, North Dakota (Avg Atmospheric Pressure =13.86 psia) 

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

"""Y4"-,'!>"'_~~"""~l',t_"'.(''''''0'~,.,.... , .....,.,..,..,..'t'''I':-~~~~'r''I!'$I~~''!'~'''~·''''''''!'_"""ffl="'~>'I'm'I"f'It~,..~,!"'>W, .....~_"~",_..,_, ..('"""""·,,,,,~,..,.,...,..._~·,,~.,.:--,·" ~'~""'~"'k,,,.:\,~ -'{'''7_'"1"''~'-'W'''''''''''"'''''~<''i'r='''''f'_''"'t:.'·",,1''·N'':',,*,,''''~'·'''"'_""''''''~~~~,",:,:,''''''''~;l,''''''':'&'n1J'''!'I1)<''':''~''''''''~''''_'~_~ ..~rIII'''' _________
• • • • 

TANKS 4.0 Report Page 2 of6 

TANKS 4.0.9d 

Emissions Report - Detail Format 

Liquid Contents of Storage Tank 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

.----~----------------- --..----...--.---.-- LIquid 

T

Daily Liquid Surf. 

emperalUre (deg F) 

Bulk 

Temp vapor Pressure (psis) 

Vapor 

Mol. 

LIquid 

Mass 

vapor 

Mass Mol. Basis for Vapor Pressure 

MixlureJCompOnent Month Avg, Min. Ma •. (deg F) Avg. MII1. Ma•. Weight. Fract. Fract. Weight Calculations 

--------~---.-----------------------

Distillate fuel oil no. 2 All 50.16 39.72 60,64 44.68 0.0045 0.0031 0.0067 130.0000 188.00 Option 1: VP50 .0045 VP60 •.0065 

file:IIC:\Program Files\Tanks409d\summarydisplay.htm 9/2912011 
• TANKS 4.0 Report • • Page 3 of6 • 

TANKS 4.0.9d 


Emissions Report - Detail Format 


Detail Calculations (AP-42) 


1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

Annual Emission Calcaulatlons 

Standing Losses (Ib): 

Vapor Space Volume (cu It): 

Vapor Density (lb/cu It): 

Vapor Space Expansion Factor: 

Vented Vapor Saturation Factor: 

Tank Vapor Space Volume: 

Vapar Space Volume (cu It): 

Tank Diameter (It): 

EflecliYe Diameter (It): 

Vapor Space Outage (II): 

Tank Shell Length (ft): 

Vapor Density 

Vapor Density (II)/cu It): 

Vapor Molecular Weight (Ibltb·mole): 

Vapor Pressure at Dally AYerage Liquid 

Surtace Temperatule (psia): 

Dally AYg. Liquid SUltace Temp. (deg. R): 

Daily AYelage Amblen! Temp. (deg. Fl: 

Ideal Gas Constanl R 

(psla cull I (Ib·mol·dag R»: 

Liquid Bulk Temperature (deo. R): 

Tank Paint Solar Absorptance {Shell}: 

Daily Total Solar Insula lion 

Faclor (Blulsqfl day): 

Vapor Space Expansion Factor 

Vapor Space Expansion Faclor: 

Daily Vapor Tempera,"re Range (dog. R): 

Daily Vapor Pressure Range (psia): 

Brealher Vent Press. Sening Range(psla): 

Vapor Plessure al Daily Ayerage Liquid 

Surtace Temperature (pslal: 

Vapor Pressure al Daily Minimum Liquid 

Surtace Temperature (psia): 

Vapar Pressure at Dally Maximum Liquid 

Surtace Temperature (PSIa): 

Daily Ayg. Liquid Surtace Temp. (dag R): 

Daily Min. Liquid Surlace Temp. (dag R): 

Daily Max. Liquid Surtace Temp. (deo R): 

Daily Ambienl Temp. Range (dag. R): 

Venled Vapar Saluration Factor 

Vented Vapor Saluralion Factor: 

Vapar Pressure at Dally Ayeraga Liquid: 

Surface Temperature (psia): 


Vapar Space Outage (It): 


Working Losses (Ib): 

Vapar Molecutar Weight (IbIIb-mole): 

Vapor Pressure at Daily AYerage Liquid 

Surface Temperalure (psia): 


Annual Net Throughpul (gallyr.): . 


0.2654 

86.5719 

0.0001 

0.0780 

0.9995 

86.5719 

4.1800 

7.2797 

2.0800 

10.0000 

0.0001 

130.0000 

0.0045 

509.8466 

41.5958 

10.731 

5043458 

0.6800 

1,276.2450 

0.0780 

41.8377 

0.0036 

0.0600 

0.0045 

0.0031 

0.0067 

509.8466 

499.3872 

520.3060 

24.3583 

0.9995 

0.0045 

2.0800 

5.6720 130.0000 

0.0045 

2,244,312.0000 

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

TANKS 4.0 Report Page 4 of6 

Annual Turnovers: 2,244.3120 


Turnover Factor: 0.1800 


Tank Diameter (ft): 4.1600 


Working Loss Product Faclor: 1.0000 


Total Losses (Ib)' 5.9375 

file:IIC:\Program Files\Tanks409d\summarydisplay.htm 9/2912011 
• TANKS 4.0 Report • • Page 5 of6 • 

TANKS 4.0.9d 

Emissions Report ~ Detail Format 

Individual Tank Emission Totals 

Emissions Report for: Annual 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

II Losses(lbs) I 

[<::omponerits II Working Lossil Breathing LosslI Total Emissionsl 

IDistiliate fuel oil no. 2 II 5.67/1 0.2711 5.941 

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

TANKS 4.0 Report Page 60f6 

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