DAKOTA-3 E&P CO;\IPANY, LLC

a subsidia'1' of Williams

100 I 17th Streel, Suile 1200

Denver, CO 80202

303/527-3900

December 21, 20 II

Ms. Kathleen Paser

Minor NSR Permitting Coordinator

U.S. EPA, Region 8

1595 Wynkoop Avenue, 8P-AR

Denver, CO 80202-1129

Duplicate submittal provided via e-mail to:

r8airpermitting@epa.gov

Re: Synthetic Minor Source Permit Application for the Maggie Old Dog 19-18H Pad

Dear Ms. Paser:

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

Source Permit Application for the Maggie Old Dog 19-18H Pad. This application is being submitted in

accordance with the requirements ofthe August 29, 2011 Consent Agreement, regarding compliance with

the Federal Minor New Source Review Rule.

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

JoDell.Mizoue@Williams.com.

Sincerely,

Williams Dil1tPUUy, LLC--"-.-..--__

JoDell Mizoue, P.E

StaffEnvironmental Specialist

Attachment

cc; File

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

New Town, ND 58763-9404

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

(letter Only)
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 

Region 8 Air Program 

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

Check List – Application for New Construction 

(Form NEW) 

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 of the type of information that Region 8 will use to process information on your proposed 

project. While submittal of this form is not required, it does offer details on the information we will use to complete your 

requested approval and providing the information requested may help expedite the process. Use of application forms for 

this program is currently under Office of Management and Budget review and these information request forms will be 

replaced/updated after that review is completed. 

Please submit information to 

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: 

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

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

 Maggie Old Dog 19-18H Pad 

3. Type of Operation 

 Oil and Gas Production 

4. Portable Source? Yes No 

5. Temporary Source? Yes No 

6. NAICS Code 

 213111 

7. SIC Code 

 1311 

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

9. Reservation* 

 FBIR 

10. County* 

 Dunn 

11a. Latitude* 

47.7916087 

11b. Longitude* 

-102.6347529 

12a. Quarter Quarter Section* 

SESW 

12b. Section* 

 19 

12c. Township* 

 T150N 

12d. Range* 

 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 of the 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 

Date of the Permit Action N/A
C. CONTACT INFORMATION 

Company Contact: JoDell 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

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

Mailing Address

Email Address 

Telephone Number Facsimile Number

Facility Contact: Same as above Title 

Mailing Address

Email Address 

Telephone Number Facsimile Number

Compliance Contact: Same as above Title 

Mailing Address

Email Address 

Telephone Number Facsimile Number
D. ATTACHMENTS 

Include all of the 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, PM10, PM2.5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile 

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

mist (H2SO4), 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 Potential Emissions 

 (tpy) 

Proposed Allowable 

Emissions 

 (tpy) 

PM - Particulate Matter 

PM10 - 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 

H2SO4 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur 

Compounds

PM 0.53 0.64 

PM10 0.53 0.64 

PM 2.5 0.53 0.64 

SOx 0.16 0.16 

NOx 35.52 37.70 

CO 67.50 79.38 

VOC 1278.69 50.66 

Pb Negligible Negligible 

Fluorides Negligible Negligible 

H2SO4 Negligible Negligible 

H2S Negligible Negligible 

TRS Negligible Negligible 

RSC Negligible Negligible 

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

sources, pursuant to CAA Section 302(j): 

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

(b) Kraft pulp mills; 

(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; 

(l) Phosphate rock processing plants; 

(m) Coke oven batteries; 

(n) Sulfur recovery plants; 

(o) 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 111 or 

112 of the Act.
E(ii) – Proposed New Construction at an Existing Facility or Modification of an Existing Facility 

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

Pollutant Current 

Actual 

Emissions 

(tpy) 

Current 

Allowable 

Emissions 

(tpy) 

Post-Change 

Potential 

Emissions 

(tpy) 

Post-Change 

Allowable 

Emissions 

(tpy) 

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

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

PM 2.5 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 N/A N/A 

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

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

H2SO4 N/A N/A N/A N/A 

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

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

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

PM - Particulate Matter 

PM10 - Particulate Matter less than 10 microns in size 

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

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic Compound 

Pb - Lead and lead compounds 

NH3 - Ammonia 

Fluorides - Gaseous and particulates 

H2SO4 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur Compounds 
Page 7 of 15 

Instructions 

Use of This Form 

• Proposed new construction or modifications should first be evaluated to determine if the 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). If the proposed construction does not qualify as a major under 

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

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

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

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

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

The following exemptions apply: 

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

(2) An increase in the hours of operation 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 defined in 

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

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

unit’s potential to emit. 

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

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

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

stringent of the 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 8 of 15 

A. General Facility Information 

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

corporations, include divisions or subsidiary name, if any. 

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

contain one or more air pollution emitting units. 

3. Type of Operation: 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. 

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

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

 

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

found at the following link  North American Industry Classification System

(http://www.census.gov/epcd/naics/nsic2ndx.htm#S1). 

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

Classification System (NAICS) 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  Standard 

Industrial Classification Code (http://www.osha.gov/pls/imis/sic_manual.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. 

11a & 11b. 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 1/4 Section/Section/Township/Range. 

(e.g., SW 1⁄4, NE 1⁄4 /S36/T10N/R21E). 
Page 9 of 15 

B. Current Permit Information 

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

Minor New Source Review (MNSR), Prevention of Significant 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 of the process flow diagram to be submitted 

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

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

What are the raw materials? 

What are the properties of the raw materials? 

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

How will the raw materials be affected by this process? 

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

Etc.... 

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

and weeks per year. 

3. A list of the 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 10 of 15 

 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 

of material 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 

of material 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 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. 

1. Include manufacturer specifications and guarantees for each control device.
Page 11 of 15 

Criteria Pollutant Emissions Estimates 

 Estimates of Current Actual Emissions, Current Allowable Emissions, Post-Change Uncontrolled 

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

matter, PM10, 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 (H2SO4), hydrogen sulfide (H2S), total reduced sulfur (TRS) and 

reduced sulfur compounds, including all calculations for the estimates. 

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

to total emissions. 

2. The information should include all of the 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. (i.e. 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/chief/efpac/index.html. 

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

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

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

by 2,000 (which is the number of pounds 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 (lbs/hr) 

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

number of pounds 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 12 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 of hours in a year) and 

dividing by 2,000 (which is the number of pounds 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 of hours 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 of the 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. If the allowable emissions of an 

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

calculation.

• For each unpermitted emissions unit (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 of the 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. If the 

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

replacement, use zero in the calculation.
Page 13 of 15 

 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) of proposed emissions be performed if there is reason to be concerned that new 

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

Prevention of Significant Deterioration (PSD) increment violation. 

In addition, if the 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 of the environmental impact of the activities proposed. 

2. Modeling of proposed 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) If you have questions about whether modeling may be necessary based on the 4th criteria 

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

Gail Tonnesen 

Region 8 Modeling Lead 

Tonnesen.gail@epa.gov

303-312- 6113 
Page 14 of 15 

What Kind of Air 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 1: Qualitative Air Quality Assessment 

Narrative description of the 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. 

If a 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/scram/dispersion_screening.htm. A pre-approved modeling protocol is 

not necessary prior to conducting a Screening Analysis. 

4. If the proposed new or modified emission increases do not increase ambient concentrations of a 

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

further modeling is necessary. 

Significant Impact Levels 

Pollutant Averaging Period Class II Area SIL 

(ug/m3) 

Class I Area SIL 

(ug/m3) 

SO2

1 hr 3 ppb or 7.8 ug/m3 (interim) ---- 

3 hr 25 1.0 

24 hr 5 0.2 

Annual 1 0.08 

PM2.5

24 hr 0.07 1.2 

Annual 0.06 0.3 

PM10

24 hr 5 0.2 

Annual 1 0.08 

NO2

1 hr 4 ppb or 7.5 ug/m3 (interim) ---- 

Annual 1 0.08 

CO 1 hr 2,000 ppb 

8 hr 500 ppb 

Note: The Class I area SILs are provided as guidance and have not been formalized by EPA. 
Page 15 of 15 

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

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

6 should be performed based an approved protocol.

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

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

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

1. Approved Modeling Protocol 

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

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

been approved. 

2. Modeling Results 

In all cases, the modeling results should include the name of the 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 of any listed species or result in the destruction or adverse modification of 

designated critical habitat of such species. 

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

species that you may be readily aware of that 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 of your 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. 
	

		

	

	

	
	

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Facility Information

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well 

#4, Well #5, Well #6, Well #7 Name of the facility and the well number.

Not Producing Yet Approximate first date of production or the date of modification of the facility.

Production Data Description

BOPD 3807 Average daily production in barrels of oil per day (BOPD), based on the predicted first 30 days of production.

Mscfd 2646 Average daily production of gas in Mscf per day, based on the predicted first 30 days of production.

Decline Factor 0.505 Expected decline factor for the first year of operation. Based on data from previously producing wells in the same field and formation.

Adjusted BOPD 1924 This is the calculated BOPD expected to be produced using the above entered decline factor.

Adjusted Produced Gas (Mscfd) 1337 This is the calculated mcfd of gas the well is expected to produce using the above entered decline factor.

Oil/Condensate Tank Data Description

Flash Gas Method: Process Simulator Use the drop down menu to choose the appropriate flash gas method.

Process Simulator Estimated scf/bbl 39.1 The scf/bbl from direct measurement or representative sample. Based on representative E&P Tank Emission Summary Output.

Estimated Tank Vapors (scfd) 75216.551 This is the estimated scfd of tank vapors based on the following: adjusted BOPD multiplied by the scf/bbl entered on Line 9.

Lower Heating Value 2338.03 Lower heating value (Btu/scf) of tank vapors. Based on representative E&P Tank Emission Summary Output.

Molecular Weight 40.93 Molecular weight of the tank vapors in pounds per pound-mole (lb/lb-mole). Based on representative E&P Tank Emission Summary Output.

VOC% 73.87712 VOC weight fraction of the tank vapor gas (C3+). Based on representative E&P Tank Emission Summary Output.

VOC TPY/BOPD Emission Factor 0.6514 Based on representative E&P Tank Emission Summary Output. (Summary Output creates a linear relationship between TPY and BOPD) 

HAP% 0.7286263 HAP weight fraction of the tank vapor gas. Based on representative E&P Tank Emission Summary Output.

HAP TPY/BOPD Emission Factor 0.0056 Based on representative E&P Tank Emission Summary Output. (Summary Output creates a linear relationship between TPY and BOPD) 

CO2% 0.29% CO2 weight fraction of the tank vapor gas. Based on representative E&P Tank Emission Summary Output.

CH4% 2.15% CH4 weight fraction of the tank vapor gas. Based on representative E&P Tank Emission Summary Output.

H2S weight % 0.09% H2S weight percent of the tank vapor gas. Based on representative E&P Tank Emission Summary Output.

H2S mole % 0.11% H2S mole percent of the tank vapor gas. Based on representative E&P Tank Emission Summary Output.

Enclosed Smokeless Combustor Use the drop down menu to choose the appropriate emission control type.

Control Destruction Efficiency 98% Control efficiency of any applicable controls. This is a fixed number based on control type.

RED = No input required. This is a calculated value.

Input Data

Dakota-3 E&P Company, LLC

GREEN = Requires input
Facility Information

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well 

#4, Well #5, Well #6, Well #7 Name of the facility and the well number.

RED = No input required. This is a calculated value.

Input Data

Dakota-3 E&P Company, LLC

GREEN = Requires input

Treater Gas Data Description

Btu/scf 1700.3866 Btu/scf of wellstream gas. (From representative field gas analysis)

Molecular Weight 29.646857 Average molecular weight of the wellstream gas in lb/lb-mole. (From representative field gas analysis)

Specific Gravity 1.0236429 If necessary to convert specific gravity to molecular weight, enter the specific gravity of the wellstream gas. (From representative field gas analysis)

Average Molecular Weight 29.647 (From representative field gas analyses)

VOC% 45.94% VOC weight fraction of the wellstream gas (Note: Weight%, not Mole%). (From representative field gas analysis)

HAP% 1.28% HAP weight fraction of the wellstream gas. (Note: Weight%, not Mole%). (From representative field gas analysis)

CO2% 0.863% CO2 weight fraction of the wellstream gas. (Note: Weight%, not Mole%). (From representative field gas analysis)

CH4% 25.747% CH4 weight fraction of the wellstream gas. (Note: Weight%, not Mole%). (From representative field gas analysis)

H2S weight % 0.000% H2S weight percent of the wellstream gas. (From representative field gas analysis)

H2S mole % 0.000% H2S mole percent of the wellstream gas. (From representative field gas analysis)

Connected to sales line Use the drop down menu to choose the appropriate emission control type.

Control/Capture Efficiency 100% If routed to pipeline, assumed 100% capture of gas. If flared, control efficiency of any applicable controls (combustor, pit flare, utility flare, etc).

Treater Burner(s) Description

Total Btu/hr 5250000 Total burner rating for the heater treater burner(s) in btu/hr. If there are multiple burners, add the total heat input together.

Hours of Operation 8,760 The burner(s) is/are assumed to operate 8,760 hours per year.

Truck Loading Description

Oil is sold through LACT Use the drop down menu to choose the appropriate oil sales method. If oil is sold through a LACT, no input values are required in Lines 30-35.

Submerged loading: dedicated normal service 0.6 Use the drop down list to choose the appropriate mode of operation. The saturation factor will automatically be selected based on mode of operation.

Molecular Weight 40.93 Molecular weight of tank vapors in lb/lb-mole. Assumed same molecular weight as flashing emissions from representative E&P Tanks data.

Vapor Pressure 2.30 True vapor pressure of liquid loaded, pounds per square inch absolute (psia) If no site specific data is available, please refer to Table 2 on Truck Loading tab.

Temperature 50.00 Temperature of bulk liquid loaded in Fahrenheit. If no site specific data is available, use an estimated average annual temperature.

Load Rate (bbl/hr) 180 Load rate of liquid loaded in barrels per hour.

Load Time (hrs) 1.00 The time it takes to loadout one load (hrs).

Pneumatic Pumps and Contollers (None) Description

Glycol Dehydrator (None) Description
Facility:

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well 

#1, Well #2, Well #3, Well #4, 

Well #5, Well #6, Well #7

VOC HAP NOx PM PM10 PM2.5 CO H2S SO2 HCHO

Oil/Condensate Tanks 1253.10 10.80 N/A N/A N/A N/A N/A N/A N/A Negligible

Casing Head Gas 17.54 0.49 2.82 0.19 0.19 0.19 15.35 NA 0.00 0.00

Treater Burner 0.12 0.04 2.25 0.17 0.17 0.17 1.89 N/A 0.01 Negligible

RICE Engine 7.93 1.19E-01 30.44 0.18 0.18 0.18 50.26 N/A 1.45E-01 0.12

Truck Loading N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Fuel Storage Tank Negligible Negligible N/A N/A N/A N/A N/A N/A N/A N/A

Pneumatic Pump N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Pneumatic Controllers N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Glycol Dehydrator N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Totals (TPY) 1278.69 11.45 35.52 0.53 0.53 0.53 67.50 0.00 0.16 0.12

VOC HAP NOx PM PM10 PM2.5 CO H2S SO2 HCHO

Oil/Condensate Tanks 25.06 0.22 2.18 0.10 0.10 0.10 11.87 N/A N/A Negligible

Casing Head Gas 17.54 0.49 2.82 0.19 0.19 0.19 15.35 0.00 0.00 0.00

Treater Burner 0.12 0.04 2.25 0.17 0.17 0.17 1.89 N/A 0.01 Negligible

RICE Engine 7.93 1.19E-01 30.44 0.18 0.18 0.18 50.26 N/A 1.45E-01 0.12

Truck Loading N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Fuel Storage Tank Negligible Negligible N/A N/A N/A N/A N/A N/A N/A N/A

Pneumatic Pump N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Pneumatic Controllers N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Glycol Dehydrator N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

Totals (TPY) 50.66 0.87 37.70 0.64 0.64 0.64 79.38 0.00 0.16 0.12

a

Emissions of lead and lead compounds, fluorides, sulfuric acid mist, total reduced sulfur, and reduced sulfur compounds are assumed to be negiligable for upstream oil & gas operations on the FBIR.

Criteria Pollutants

Criteria Pollutantsa

Dakota-3 E&P Company, LLC

Allowable Potential to Emit

Emission Summary

Uncontrolled Potential to Emit
Facility:

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well 

#1, Well #2, Well #3, Well #4, 

Well #5, Well #6, Well #7

Dakota-3 E&P Company, LLC

CO2 CH4 N2O CO2 CH4 N2O

Oil/Condensate Tanks N/A 31.86 N/A 1651.47 0.00 0.03

Casing Head Gas 2944.43 9.83 0.00 2944.43 9.83 0.00

Treater Burner 2705.29 0.15 0.03 2705.29 0.15 0.03

RICE Engine 2.65E+02 0.40 0.08 2.65E+02 0.40 0.08

Truck Loading 0.00 0.00 N/A 0.00 0.00 N/A

Fuel Storage Tank N/A N/A N/A N/A N/A N/A

Pneumatic Pump N/A N/A N/A N/A N/A N/A

Pneumatic Controllers N/A N/A N/A N/A N/A N/A

Glycol Dehydrator N/A N/A N/A N/A N/A N/A

Totals (TPY) 5914.67 42.24 0.11 7566.14 10.38 0.15

GHG Mass Emissions (tpy): 5957.02 GHG Mass Emissions (tpy): 7576.67

CO2e (tpy): 6836.99 CO2e (tpy): 7829.24

Applicable to the Tailoring Rule?: No

b Hydrofluorocarbons (HFCs), Perfluorocarbons (PFCs), and Sulfur Hexafluorides (SF6) emissions are not created from O&G production operations.

Actual

Greenhouse Gasesb

Potential To Emit

Greenhouse Gasesb
BOPD

scf/day

Btu/scf

lb/lb-mole

tpy/bopd

HAPs:

Benzene wt Fraction

Toluene wt Fraction

E-Benzene wt Fraction

Xylene wt Fraction

n-Hexane wt Fraction

2,2,4-Trimethylpentane

wt Fraction

HAP Emission Factor tpy/bopd

98% destruction efficiency of the VOC gas.

0.0203%

0.0021%

0.0110%

0.6343%

0.0116%

0.0493%

CH4 wt Fraction

0.006

Controlled emissions are calculated based on a 

0.29%

2.15%

CO2 wt Fraction

Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Flare Gas Volume 75,217

Oil Production 1924

0.651

Lower Heating Value 2338.03

Molecular Weight 40.93

VOC wt Fraction 73.88%

VOC Emission Factor
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Uncontrolled VOCs (PTE):

DRE

Using E&P Tanks Run: 0.651 x 1923.7 x 0% = 1253.10 TPY

Controlled VOCs (Allowable):

DRE

Using E&P Tanks Run: 0.651 x 1923.7 x 98% = 25.06 TPY

Uncontrolled HAPs (PTE):

Using E&P Tanks Run: wt% DRE TPY

Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.02% x 0% = 0.07 lb/hr 0.30

E-Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.00% x 0% = 0.01 lb/hr 0.03

Toluene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 0% = 0.04 lb/hr 0.16

n-Hexane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.63% x 0% = 2.15 lb/hr 9.40

Xylene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 0% = 0.04 lb/hr 0.17

2,2,4-Trimethylpentane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.05% x 0% = 0.17 lb/hr 0.73

Uncontrolled TOTAL HAPS (TPY) 10.80

Controlled HAPs (Allowable):

Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.02% x 98% = 0.00 lb/hr 0.01

E-Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.00% x 98% = 0.00 lb/hr 0.00

Toluene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00

n-Hexane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.63% x 98% = 0.04 lb/hr 0.19

Xylene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00

2,2,4-Trimethylpentane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.05% x 98% = 0.00 lb/hr 0.01

Controlled TOTAL HAPS (TPY) 0.22

BOPD

TPY VOC/BOPD

TPY VOC/BOPD

CRITERIA POLLUTANT EMISSIONSa

BOPD

=

=

=

=

=

=

=

=

=

=

=

=

=

=
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Uncontrolled NOx:

NOx: 0 scf/hr x 2,338 Btu/scf x x 0.068 lb/MMBtu = 0.00 lb/hr

0.00 lb/hr x x 0.00 TPY

NOx Created by Combustion (Actual)

NOx: 3,134 scf/hr x 2,338 Btu/scf x x 0.068 lb/MMBtu = 0.50 lb/hr

0.50 lb/hr x x 2.18 TPY

Uncontrolled PM:

PM: 0 scf/hr x 7.6 lb/1,000,000 scf = 0.00 lb/hr

0.00 lb/hr x 8760 hr/yr x 0.00 TPY

PM Created by Combustion (Actual)

PM: 3,134 scf/hr x 7.6 lb/1,000,000 scf = 0.02 lb/hr

0.02 lb/hr x 8760 hr/yr x 0.10 TPY

1 MMBtu/1,000,000 Btu

8760 hr/yr

1 ton/2000 lb =

=

1 ton/2000 lb =

1 ton/2000 lb =

1 ton/2000 lb

1 MMBtu/1,000,000 Btu

8760 hr/yr
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Uncontrolled CO:

CO: 0 scf/hr x 2,338 Btu/scf x x 0.370 lb/MMBtu = 0.00 lb/hr

0.00 lb/hr x x 0.00 TPY

CO Created by Combustion (Actual)

CO: 3,134 scf/hr x 2,338 Btu/scf x x 0.370 lb/MMBtu = 2.71 lb/hr

2.71 lb/hr x x 11.87 TPY

a

NOx, SO2, and CO emission factors are from AP-42 Table 13.5-1

(Emission Factors for Flare Operations).

=

1 MMBtu/1,000,000 Btu

8760 hr/yr 1 ton/2000 lb

1 MMBtu/1,000,000 Btu

8760 hr/yr 1 ton/2000 lb =
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Uncombusted CO2:

wt DRE

CO2: 3,134 scf/hr x x 40.93 lb/lb-mole 0.29% x 0% = lb/hr

lb/hr x 8760 hr/yr x = TPY

CO2 Created by Combustion (Actual)

CO2: 3,134 scf/hr x 120,000.0 lb/1,000,000 scf = lb/hr

376.08 lb/hr x 8760 hr/yr x 1 ton/2000 lb = 1647.24 TPY

1/379 scf/lb-mole x

1 ton/2000 lb

0.97

4.23

376.08

REGULATED GREENHOUSE GAS EMISSIONSb

0.97
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Uncontrolled CH4:

wt DRE

CH4: 3,134 scf/hr x x 40.93 lb/lb-mole 2.15% x 0% = lb/hr

lb/hr x 8760 hr/yr x = TPY

Controlled CH4: (Actual)

wt% DRE

CH4: 3,134 scf/hr x x 40.93 lb/lb-mole 2.15% x 98% = lb/hr

lb/hr x 8760 hr/yr x = TPY

x 0.15

0.15 0.64

1/379 scf/lb-mole

1 ton/2000 lb

x 7.27

7.27 31.86

1/379 scf/lb-mole

1 ton/2000 lb
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Tanks

Uncontrolled N2O:

wt% DRE

CH4: 3,134 scf/hr x x 40.93 lb/lb-mole 0.00% x 0% = lb/hr

lb/hr x 8760 hr/yr x = TPY

N2O Created by Combustion:

CH4: 3,134 scf/hr x 2.3 lb/1,000,000 scf = lb/hr

0.01 lb/hr x 8760 hr/yr x = 0.03 TPY

b

CO2 and N2O emission factors are from AP-42 Table 1.4-2

(Emission Factors for Natural Gas Combustion).

0.00 0.00

0.01

1 ton/2000 lb

1/379 scf/lb-mole x 0.00

1 ton/2000 lb
scf/hr (Takes into account the 10% of the total

produced gas volume that is not being sold.)

Btu/scf

lb/lb-mole

HAP wt fraction

Benzene wt fraction

E-Benzene wt fraction

Toluene wt fraction

n-Hexane wt fraction

Xylene wt fraction

2,2,4-Trimethylpentane

wt fraction

CO2 wt fraction

CH4 wt fraction

hours/yr

DRE

Dakota-3 E&P Company, LLC

8760 Hours of Flaring for 

PTE:

Control Effiiciency

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

Flare Gas Volume 5,571

Lower Heating Value 1700.386571

Avg. Molecular Weight 29.65

VOC wt fraction 45.94%

1.28%

0.15%

0.01%

0.18%

0.84%

0.10%

0.00%

0.86%

25.75%

98%
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

Controlled VOCs (PTE):

wt% Control %

VOC: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 45.94% x 98% = lb/hr

4.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

Controlled VOCs (Allowable):

wt% Control %

VOC: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 45.94% x 98% = lb/hr

4.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

17.54

4.00

17.54

x

CRITERIA POLLUTANT EMISSIONSa

x 4.00
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

Controlled HAPs (PTE):

Using E&P Tanks Run: wt% Control % TPY

Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.15% x 98% = 0.01 lb/hr 0.06

E-Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00

Toluene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.18% x 98% = 0.02 lb/hr 0.07

n-Hexane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.84% x 98% = 0.07 lb/hr 0.32

Xylene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.10% x 98% = 0.01 lb/hr 0.04

2,2,4-Trimethylpentane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.00% x 98% = 0.00 lb/hr 0.00

Formaldehyde 5,571 scf/hr 7.50E-02 lb/MMscf = 0.00 lb/hr 0.00

` 0.11 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

Controlled HAPs (Allowable):

Using E&P Tanks Run: wt% Control % TPY

Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.15% x 98% = 0.01 lb/hr 0.06

E-Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00

Toluene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.18% x 98% = 0.02 lb/hr 0.07

n-Hexane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.84% x 98% = 0.07 lb/hr 0.32

Xylene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.10% x 98% = 0.01 lb/hr 0.04

2,2,4-Trimethylpentane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.00% x 98% = 0.00 lb/hr 0.00

Formaldehyde 5,571 scf/hr x 7.50E-02 lb/MMscf x 1000000 scf/MMscf = 0.00 lb/hr 0.00

` 0.11 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

=

=

=

=

0.49

=

=

=

=

=

=

=

=

=

=

0.49
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

Uncontrolled NOx (PTE):

NOx: 5,571 scf/hr x 1,700 Btu/scf x x 0.068 lb/MMBtu = 0.64 lb/hr

0.64 lb/hr x 8760 hr/yr x 2.82 TPY

NOx Created by Combustion (Actual):

NOx: 5,571 scf/hr x 1,700 Btu/scf x x 0.068 lb/MMBtu = 0.64 lb/hr

0.64 lb/hr x 8760 hr/yr x 2.82 TPY

Controlled H2S (PTE):

wt% Control %

H2S: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

0.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

Controlled H2S (Actual):

wt% Control %

H2S: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

0.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

x

0.00

=

1 Mmbtu/1,000,000 Btu

1 ton/2000 lb =

x 0.00

0.00

1 ton/2000 lb

1 Mmbtu/1,000,000 Btu

0.00
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

SO2 Created by Combustion (PTE):

wt% Control %

SO2 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

0.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

SO2 Created by Combustion (Actual):

wt% Control %

SO2 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

0.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

CO Created by Combustion (PTE):

CO: 5,571 scf/hr x 1,700 Btu/scf x x 0.370 lb/MMBtu = 3.50 lb/hr

3.50 lb/hr x 8760 hr/yr x 15.35 TPY

CO Created by Combustion (Actual):

CO: 5,571 scf/hr x 1,700 Btu/scf x x 0.370 lb/MMBtu = 3.50 lb/hr

3.50 lb/hr x 8760 hr/yr x 15.35 TPY

0.00

0.00

0.00

=

0.00

=

1 ton/2000 lb

x

1 Mmbtu/1,000,000 Btu

1 ton/2000 lb

x

1 Mmbtu/1,000,000 Btu
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

PM Created by Combustion (PTE):

PM: 5,571 scf/hr x 7.6 = 0.04 lb/hr

0.04 lb/hr x 8760 hr/yr x 0.19 TPY

PM Created by Combustion (Actual):

PM: 5,571 scf/hr x 7.6 = 0.04 lb/hr

0.04 lb/hr x 8760 hr/yr x 0.19 TPY

=

 lb/1,000,000 scf

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

 lb/1,000,000 scf

1 ton/2000 lb =

1 ton/2000 lb

a

NOx, SO2, PM, & CO emission factors are from AP-42 Table 13.5-1 and Table 1.4-2
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

CO2 (PTE):

CO2 Entrained in the Produced Gas:

Control %

CO2: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.86% x 98% = lb/hr

3.76 lb/hr x 8760 hr/yr x 1 ton/2000 lb = 16.46 TPY

CO2 Created by Combustion:

CO2: 5,571 scf/hr x 120,000.0 = 668.48 lb/hr

`

668.48 lb/hr x 8760 hr/yr x 2927.96 TPY

2944.43 TPY

REGULATED GREENHOUSE GAS EMISSIONSb

1 ton/2000 lb =

x 3.76

 lb/1,000,000 scf

Total CO2 Emitted (PTE):
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

CO2 (Actual):

CO2 Entrained in the Produced Gas:

wt% Control %

CO2: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.86% x 98% = lb/hr

3.76 lb/hr x 8760 hr/yr x 1 ton/2000 lb = 16.46 TPY

CO2 Created by Combustion: `

CO2: 5,571 scf/hr x 120,000.0 = 668.48 lb/hr

`

668.48 lb/hr x 8760 hr/yr x 2927.96 TPY

2944.43 TPY

Controlled CH4 (PTE):

wt% Control %

CH4: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 25.75% x 98% = lb/hr

2.24 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

Controlled CH4 (Actual):

wt% Control %

CH4: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 25.75% x 98% = lb/hr

2.24 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY

x 2.24

9.83

Total CO2 Emitted (Allowable):

1 ton/2000 lb =

 lb/1,000,000 scf

x

2.24

9.83

x

3.76
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Casing Head Gas

N2O Created by Combustion (PTE):

N2O: 5,571 scf/hr x 2.2 = 1.23E-02 lb/hr

1.23E-02 lb/hr x 8760 hr/yr x 3.06E-03 TPY

N2O Created by Combustion (Actual):

N2O: 5,571 scf/hr x 2.2 = 1.23E-02 lb/hr

1.23E-02 lb/hr x 8760 hr/yr x 3.06E-03 TPY

(Emission Factors for Natural Gas Combustion).

1 ton/2000 lb =

 lb/1,000,000 scf

 lb/1,000,000 scf

b

CO2 and N2O emission factors are from AP-42 Table 1.4-2

1 ton/2000 lb =
5,250,000 Btu/hr This burner rating reflects the combined size of all of the proposed heater treater burners at the facility.

NOx: 0.10 lb/MMBtu x 5.25 MMBtu/hr = 0.515 lb/hr

0.5147 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 2.254 TPY

CO: 0.08 lb/MMBtu x 5.25 MMBtu/hr = 0.432 lb/hr

0.43 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 1.894 TPY

SO2: 5.88E-04 lb/MMBtu x 5.25 MMBtu/hr = 0.003 lb/hr

3.09E-03 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 0.014 TPY

PM: 0.01 lb/MMBtu x 5.25 MMBtu/hr = 0.039 lb/hr

0.04 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 0.171 TPY

Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Heater Treater Burnera

Burner Rating
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Heater Treater Burnera

VOC: 0.01 lb/MMBtu x 5.25 MMBtu/hr = 0.028 lb/hr

0.03 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 0.124 TPY

HAP: 0.002 lb/MMBtu x 5.25 MMBtu/hr = 0.010 lb/hr

9.73E-03 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 0.043 TPY

CO2 117.647 lb/MMBtu x 5.25 MMBtu/hr = 617.647 lb/hr

6.18E+02 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 2,705.294 TPY
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Heater Treater Burnera

CH4: 0.007 lb/MMBtu x 5.25 MMBtu/hr = 0.035 lb/hr

3.47E-02 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 0.152 TPY

N2O: 0.001 lb/MMBtu x 5.25 MMBtu/hr = 0.007 lb/hr

6.94E-03 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 0.030 TPY

NOx TPY

CO TPY

SO2 TPY

PM TPY

VOC TPY

HAP TPY

CO2 TPY

CH4 TPY

N2O TPY

2705.29

0.15

0.03

1.89

0.12

0.04

0.01

0.17

a

NOx, CO, CO2, & VOC Emission Factors are from AP-42 Table 1.4-1 and 1.4-2 (Emission Factors for

Nitrogen Oxides (N2O) and Methane come from Table C-1 of Subpart W).

2.25
Saturation Vapor Molecular Temp + Load Loss

Factor (S) Pressure (P) Weight (MW) 460 lb/1000 gal

12.46 x 0.60 x 2.30 x 40.93 / 510.00 = 1.38

LL Truck Load Load Time

lb/1,000 gal Rate bbl/hr hrs gal/bbl

1.38 x 180.00 / 1.00 x 42.00 = 10.43

LL Annual Emissions

lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 

1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 15.03

VOC

Emissions

Uncontrolled Control % TPY

15.03 100% 0.00 0.00

Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Truck Loadout Emission Calculation

Total Gas 

Emissions lb/hr

Uncontrolled 

C3+ VOC tpy
LL Annual Emissions

lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 

1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 0.15

HAPs

Emissions

Uncontrolled Control % TPY

0.15 100% 0.00 0.00

LL Annual Emissions

lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 

1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 0.06

CO2

Emissions

Uncontrolled Control % TPY

0.06 100% 0.00 0.00

LL Annual Emissions

lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 

1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 0.44

CH4

Emissions

Uncontrolled Control % TPY

0.44 100% 0.00 0.00

Uncontrolled 

HAPs tpy

Uncontrolled 

CO2 tpy

Uncontrolled 

CH4 tpy
Combined Diesel Engines

Hours of Operation 8760

Maximum HP Rating 1925

NOx g/hp-hr 1.49E+00

CO g/hp-hr 2.61E+00

SO2 g/hp-hr 4.52E-06

PM g/hp-hr 4.85E-06

VOC g/hp-hr 1.42E-01

HAP g/bh-hr 1.02E-06

CO2 g/bh-hr 2.54E-03

CH4 g/bh-hr 2.10E-02

N2O g/hp-hr 4.20E-03

Recycle Pump

Hours of Operation 8760

Maximum HP Rating 56

NOx g/hp-hr 4.99E+00

CO g/hp-hr 3.16E+00

SO2 g/hp-hr 2.68E-01

PM g/hp-hr 3.27E-01

VOC g/hp-hr 9.80E+00

HAP g/hp-hr 2.20E-01

CO2 g/bh-hr 4.90E+02

CH4 g/hp-hr 2.10E-02

N2O g/hp-hr 4.20E-03

Description

Engine is assumed to operate 8,760 hours per year.

Manufacturer's maximum hp rating.

AP-42 Table 3.3-1

AP-42 Table 3.3-1

AP-42 Table 3.3-1

AP-42 Table 3.3-1

AP-42 Table 3.3-1

40 CFR 98 Subpart C, Table C-2

40 CFR 98 Subpart C, Table C-2

AP-42 Table 3.3-1

AP-42 Table 3.3-1

AP-42 Table 3.3-1

AP-42 Table 3.3-1

Manufacturer Guarantee (40 CFR 63 Subpart IIII requirements), see Attachment F

AP-42 Table 3.3-1

AP-42 Table 3.3-1

40 CFR 98 Subpart C, Table C-2

40 CFR 98 Subpart C, Table C-2

Dakota-3 E&P Company, LLC

RICE Input Data

Description

Engine is assumed to operate 8,760 hours per year.

Manufacturer's maximum hp rating.

Manufacturer Guarantee (40 CFR 63 Subpart IIII requirements), see Attachment F

Manufacturer Guarantee (40 CFR 63 Subpart IIII requirements), see Attachment F
ENGINE #1

1925 MAX HP 0% NOx DRE 0% CO DRE 0% VOC DRE 0% SO2 DRE 0% HAP DRE 0% PM DRE

##### #### ##### #### ### 100.00%

NOx: 1.49E+00 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 6.33E+00 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 2.77E+01 NOx TPY 

CO: 2.61E+00 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 1.11E+01 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 4.86E+01 CO TPY 

SO2: 4.52E-06 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 1.92E-05 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 8.40E-05 SO2 TPY 

PM: 4.85E-06 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 2.06E-05 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 9.02E-05 PM TPY 

VOC: 1.42E-01 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 6.02E-01 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 2.64E+00 VOC TPY 

HAP: 1.02E-06 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 4.33E-06 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 1.90E-05 HCHO TPY 

CO2: 2.54E-03 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 1.08E-02 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 4.71E-02 CO2

CH4: 2.10E-02 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 8.91E-02 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 3.90E-01 CH4

N2O: 4.20E-03 g/HP-HR 1925 HP x 1 lb / 453.6 grams = 1.78E-02 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 7.81E-02 N2O

Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Reciprocating Engine Emissions 

x

x

x

x

x

x

x

x

x
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Reciprocating Engine Emissions 

56 MAX HP 0% CO DRE 0% VOC DRE 0% SO2 DRE 0% HAP DRE 0% PM DRE

##### #### ##### #### ### 100.00%

NOx: 4.99E+00 g/HP-HR 56 HP x 1 lb / 453.6 grams x 0.62 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 2.70E+00 NOx TPY 

CO: 3.16E+00 g/HP-HR 56 HP x 1 lb / 453.6 grams x 0.39 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 1.71E+00 CO TPY 

SO2: 2.68E-01 g/HP-HR 56 HP x 1 lb / 453.6 grams = 3.31E-02 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 1.45E-01 SO2 TPY 

PM: 3.27E-01 g/HP-HR 56 HP x 1 lb / 453.6 grams = 4.04E-02 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 1.77E-01 PM TPY 

VOC: 9.80E+00 g/HP-HR 56 HP x 1 lb / 453.6 grams x 1.21 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 5.30E+00 VOC TPY

HAP: 2.20E-01 g/HP-HR 56 HP x 1 lb / 453.6 grams = 0.03 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 1.19E-01 HAP TPY 

CO2: 4.90E+02 g/HP-HR 56 HP x 1 lb / 453.6 grams = 6.05E+01 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 2.65E+02 CO2 TPY 

CH4: 2.10E-02 g/HP-HR 56 HP x 1 lb / 453.6 grams = 2.59E-03 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 1.14E-02 CH4 TPY

N2O: 4.20E-03 g/HP-HR 56 HP x 1 lb / 453.6 grams = 5.19E-04 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 2.27E-03 N2O TPY

ENGINE #2

x

x

x

x

NOx DRE

x

x

x

x

x
Dakota-3 E&P Company, LLC

Maggie Old Dog 19-18H Pad

Associated Wells:

Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

Reciprocating Engine Emissions 

3.04E+01

5.03E+01

1.45E-01

1.77E-01

7.93E+00

1.19E-01

2.65E+02

4.02E-01

8.03E-02

SO2 TPY 

CO2 TPY 

CH4 TPY

N2O TPY

TOTALS

NOx TPY 

CO TPY 

VOC TPY 

PM TPY 

HAP TPY 
Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS 

• E&P Tanks Emission Summary

• E&P Tanks Linear Relationship (Emission Factor)
Mandaree Field 1000 BOPD wt%

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

* Project 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[psig]

Separator Temperature : 82.50[F]

Ambient Pressure : 14.70[psia]

Ambient Temperature : 70.00[F]

C10+ SG : 0.8000

C10+ MW : 235.14

-- Low Pressure Oil ----------------------------------------------------------------------

 No. Component wt %

 1 H2S 0.0014

 2 O2 0.0000

 3 CO2 0.0042

 4 N2 0.0015

 5 C1 0.0320

 6 C2 0.3654

 7 C3 1.2089

 8 i-C4 0.3443

 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 C10+ 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] [lb/hr] 

Page 1---------------------------------------------------------------- E&P TANK 

Total HAPs 8.550 1.952 

Total HC 812.744 185.558 

VOCs, C2+ 796.480 181.845 

VOCs, C3+ 612.595 139.862 

Page 1
Mandaree Field 1000 BOPD wt%

 

Uncontrolled Recovery Info. 

 Vapor 40.2300 [MSCFD] 

 HC Vapor 40.0300 [MSCFD] 

 GOR 40.23 [SCF/bbl] 

-- Emission Composition ------------------------------------------------------------------

No Component Uncontrolled Uncontrolled 

 [ton/yr] [lb/hr] 

1 H2S 0.689 0.157 

2 O2 0.000 0.000 

3 CO2 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 i-C5 17.863 4.078 

11 n-C5 24.862 5.676 

12 C6 8.648 1.974 

13 C7 13.803 3.151 

14 C8 10.281 2.347 

15 C9 3.270 0.747 

16 C10+ 0.004 0.001 

17 Benzene 0.234 0.053 

18 Toluene 0.136 0.031 

19 E-Benzene 0.027 0.006 

20 Xylenes 0.156 0.036 

21 n-C6 7.394 1.688 

22 224Trimethylp 0.604 0.138 

 Total 816.378 186.388 

-- Stream Data ---------------------------------------------------------------------------

No. Component MW LP Oil Flash Oil Sale Oil Flash Gas W&S Gas Total Emissions

 wt % wt % wt % wt % wt % wt % 

1 H2S 34.80 0.0014 0.0010 0.0000 0.0873 0.0856 0.0861 

2 O2 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 i-C5 72.15 0.6508 0.6432 0.6257 2.2771 2.1480 2.1850 

11 n-C5 72.15 1.2185 1.2094 1.1888 3.1795 2.9854 3.0410 

12 C6 86.16 1.3933 1.3945 1.3984 1.1369 1.0640 1.0850 

13 C7 100.20 6.7524 6.7753 6.8342 1.8207 1.7133 1.7442 

14 C8 114.23 15.9338 16.0015 16.1730 1.3430 1.2744 1.2941 

15 C9 128.28 14.3170 14.3815 14.5440 0.4133 0.4189 0.4174 

16 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/Air] 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
Emission estimates are based on using the E&P TANK V2.0 Model, RVP Distillation Column

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

of the oil with the given inputs listed below.

Inputs:

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

Separator: 51 psig, 83 degF

Flash Valve: 13.7 psia, 50 degF

Sales Oil: API Gravity 41.9, Reid Vapor Pressure 5.90 psia, 365 days/year

Outputs:

Oil Production Rates (bbl/day) (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

Oil Storage Tank Flashing Emissions Calculation Methodology

E&P Tanks Linear Relation between Production (bbls/day) and Emissions (tons/yr)

y = 0.00855x

R2 = 1.00000

y = 0.6126x

R2 = 1

0

100

200

300

400

500

600

700

0 500 1000 1500

tons/year

bbl/day

Tank Emissions by Production Rate

Total HAPs

VOCs, C3+

Linear (Total HAPs)

Linear (VOCs, C3+)
Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

ATTACHMENT D: REPRESENTATIVE LOW PRESSURE OIL 

ANALYTICAL DATA 
Company .................... ZENERGY

Lab Number ................ CRͲ10330 Study Number.......... CRͲ2

Date Sampled .............. 7Ͳ15Ͳ2010 Date Tested............. 7Ͳ23Ͳ2010

S l Id tifi ti CROSS 2 13 H CRUDE OIL

 EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

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 ................ GPAͲ2286 Sampling Method........ YZ PISTON

 Components Mole % Weight % Liq. Vol. %

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

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

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

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

Methane ..................... 0 180 . 0 021 . 0 050 .

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

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

isoͲButane .................. 0.855 0.353 0.463

nͲButane .................... 3.974 1.640 2.072

isoͲPentane ................ 1.378 0.706 0.833

nͲPentane ................... 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

nͲHexane .................... 2.798 1.712 1.903

2,2,4ͲTrimethylpentane... 0.542 0.440 0.466

TOTALS ..................... 100.000 100.000 100.000
ADDITIONAL BETX DATA

 Components Mole % Weight % Liq. Vol. %

2-Methylpentane 1.486 0.910 1.011

3-Methylpentane 3-Methylpentane 1 024 . 0 627 . 0 696 .

n-Hexane 2.798 1.712 1.903

2,2,4-Trimethylpentane 0.542 0.440 0.466

Benzene 0.093 0.052 0.043

Toluene 0.166 0.109 0.092

Ethylbenzene 0.104 0.078 0.066

m-Xylene 0.066 0.050 0.042

p-Xylene 0.436 0.329 0.280

o-Xylene 0.116 0.087 0.074

API GRAVITY AT 60/60 F, calculated........................................................................ 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 TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated................................................ 33 400 .

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

CUBIC FEET OF GAS / GALLON OF LIQUID, as Ideal Gas .......................................... 19.106

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

LBS / GALLON OF LIQUID, calculated ...................................................................... 6.152

NOTATION: ALL CALCULATIONS PERFORMED USING PHYSICAL CONSTANTS FROM GPA 2145-09, THE TABLES

 OF PHYSICAL CONSTANTS FOR HYDROCARBONS AND OTHER COMPOUNDS OF INTEREST

 TO THE NATURAL GAS INDUSTRY.
 EXTENDED HYDROCARBON LIQUID STUDIES

 CERTIFICATE OF ANALYSIS

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

L bN ba umer............. CR-10330 CR 10330 Study Number............ St d N b CR-2B 

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

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

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

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

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

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

1-QUART 

BOTTLE

TEST PERFORMED RESULTS

API GRAVITY AT 60/60 F (ASTM D-287), observed...................... / ( ), 42.5

SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated.......... 0.8132

REID VAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 5.2 PSIG

TOTAL SULFUR CONTENT (ASTM D-5453), PPMW.................. PPMW 658.98

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

BASIC SEDIMENT AND WATER CONTENT, % BY VOLUME.... N/A

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

FREE WATER, observed......................................................... N/A

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

 OUTLINED BY THE AMERICAN SOCIETY FOR TESTING AND MATERIALS (ASTM).
5HSRUW5HSRUW(GLWRU

Chromatogram Cross 2-13H C:\GCsolution\DRO\DRO Data\08-2010\08-01-2010\Cross 2-13H.gcd - Channel 1

min

Intensity 0.0

2.5

5.0

7.5

10.0

12.5

15.0

17.5

20.0

22.5

25.0

27.5

30.0

0 50000 100000 150000 200000 250000

 1.055 / 1.137 / 1.306 / 1.405 / 1.552 / 1.668 / 

 1.729 / 1.901 / 1.979 / 2.039 / 2.109 / 2.280 / 2.417 / 2.565 / 2.667 / 2.854 / 2.949 / 3.034 / 3.092 / 3.213 / 3.342 / 3.420 / 3.539 / 3.632 / 3.773 / 3.862 / 3.965 / 4.069 / 4.148 / 4.335 / 4.448 / 4.508 / 4.583 / 4.692 / 4.751 / 4.901 / 5.021 / 5.164 / 5.365 / 5.508 / 5.608 / Decane (C10) 5.816 / 5.947 / 6.069 / 6.188 / 6.286 / 6.393 / 6.509 / 6.569 / 6.657 / 6.714 / 6.777 / 6.896 / 7.083 / 7.220 / 7.323 / 7.381 / 7.455 / 7.559 / 7.632 / 7.703 / 7.769 / 7.836 / 7.907 / 7.967 / 8.056 / 8.184 / 8.268 / 8.329 / 8.452 / 8.540 / 8.633 / 8.744 / 8.808 / 8.998 / 9.128 / 9.270 / 9.380 / 9.467 / 9.526 / 9.596 / 9.724 / 9.862 / 9.939 / 10.055 / 10.150 / 10.257 / 10.332 / 10.427 / 10.487 / 10.568 / 10.638 / 10.766 / 10.828 / 10.911 / 11.051 / 11.216 / 11.469 / 11.613 / 11.706 / 11.785 / 12.031 / 12.128 / 12.182 / 12.302 / 12.409 / 12.463 / 12.536 / 12.607 / 12.700 / 12.822 / 13.004 / 13.088 / 13.203 / 13.305 / 13.372 / 13.447 / 13.582 / 13.674 / 13.803 / 13.929 / 14.089 / 14.146 / 14.316 / 14.427 / 14.515 / 14.592 / 14.691 / 14.773 / 14.896 / 15.041 / 15.129 / 15.249 / 15.300 / 15.369 / 15.430 / 15.566 / 15.620 / 15.691 / 15.787 / 15.947 / o-terphenyl 16.113 / 16.187 / 16.339 / 16.456 / 16.570 / 16.661 / 16.813 / 16.894 / 16.979 / 17.143 / 17.306 / 17.449 / 17.519 / 17.642 / 17.787 / 17.954 / 18.052 / 18.153 / 18.222 / 18.292 / 18.434 / 18.549 / 18.723 / 18.887 / 18.991 / 19.197 / 19.331 / 19.474 / 19.663 / 19.724 / 19.785 / 19.850 / 19.927 / 19.995 / 20.077 / 20.222 / 20.182 / 20.345 / 20.443 / 20.634 / 20.789 / 20.871 / 20.945 / 21.059 / 21.134 / 21.205 / 21.310 / 21.542 / 21.695 / 21.795 / 21.855 / 21.905 / 21.966 / 22.073 / 22.181 / 22.367 / 22.425 / 22.599 / Octacosane (C28) 22.737 / 22.808 / 22.879 / 23.003 / 23.058 / 23.117 / 23.217 / 23.351 / 23.418 / 

 23.678 / 23.816 / 23.905 / 24.027 / 24.086 / 24.202 / 24.264 / 24.400 / 24.521 / 24.587 / 24.651 / 24.765 / 24.809 / 24.874 / 24.981 / 25.069 / 25.142 / 25.201 / 25.273 / 25.334 / 25.401 / 25.462 / 25.568 / 25.705 / 25.765 / 25.966 / 26.056 / 26.229 / 26.397 / 26.487 / 26.575 / 26.665 / 26.758 / 26.958 / 27.073 / 27.191 / 27.327 / 27.441 / 27.561 / 27.668 / 27.798 / 27.952 / 28.073 / 28.297 / 28.467 / 28.689 / 28.833 / 28.995 / 29.193 / 29.393 / 29.601 / 
Company .................... ZENERGY

Lab Number ................ CRͲ10330 Study Number.......... CRͲ3

Date Sampled .............. 7Ͳ15Ͳ2010 Date Tested............. 7Ͳ23Ͳ2010

S l Id tifi ti PATRICIA CHARGING 4 15 H CRUDE OIL

 EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

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

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

Sample Pressure ......... 80 PSIG Sample Temperature.... 70 F

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

Test method ................ GPAͲ2286 Sampling Method........ YZ PISTON

 Components Mole % Weight % Liq. Vol. %

Hydrogen Sulfide .......... 0.008 0.002 0.002

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

Carbon Dioxide ............ 0.014 0.004 0.004

Nitrogen ..................... 0.008 0.001 0.001

Methane ..................... 0 398 . 0 043 . 0 107 .

Ethane ....................... 1.921 0.387 0.811

Propane ..................... 3.914 1.155 1.702

isoͲButane .................. 0.862 0.335 0.445

nͲButane .................... 3.606 1.403 1.795

isoͲPentane ................ 1.238 0.598 0.715

nͲPentane ................... 2.329 1.125 1.333

Hexanes ..................... 2 180. 1 257. 1 415.

Heptanes .................... 8.849 5.934 6.445

Octanes ..................... 21.103 16.133 17.068

Nonanes ..................... 15.296 13.130 13.589

Decanes+ ................... 34.917 56.412 52.378

Benzene...................... 0.085 0.044 0.038

Toluene....................... 0.148 0.091 0.078

Ethylbenzene............... 0.060 0.043 0.037

Xylenes....................... 0.473 0.336 0.290

nͲHexane .................... 2.204 1.271 1.431

2,2,4ͲTrimethylpentane... 0.387 0.296 0.317

TOTALS ..................... 100.000 100.000 100.000
ADDITIONAL BETX DATA

 Components Mole % Weight % Liq. Vol. %

2-Methylpentane 1.272 0.734 0.826

3-Methylpentane 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 TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated................................................ 46 319 .

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

CUBIC FEET OF GAS / GALLON OF LIQUID, as Ideal Gas .......................................... 18.857

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

LBS / GALLON OF LIQUID, calculated ...................................................................... 6.232

NOTATION: ALL CALCULATIONS PERFORMED USING PHYSICAL CONSTANTS FROM GPA 2145-09, THE TABLES

 OF PHYSICAL CONSTANTS FOR HYDROCARBONS AND OTHER COMPOUNDS OF INTEREST

 TO THE NATURAL GAS INDUSTRY.
 EXTENDED HYDROCARBON LIQUID STUDIES

 CERTIFICATE OF ANALYSIS

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

L bN ba umer............. CR-10330 CR 10330 Study Number............ St d N b 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

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

1-QUART 

BOTTLE

TEST PERFORMED RESULTS

API GRAVITY AT 60/60 F (ASTM D-287), observed...................... / ( ), 41.2

SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated.......... 0.8193

REID VAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 6.6 PSIG

TOTAL SULFUR CONTENT (ASTM D-5453), PPMW.................. PPMW 940.25

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

BASIC SEDIMENT AND WATER CONTENT, % BY VOLUME.... N/A

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

FREE WATER, observed......................................................... N/A

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

 OUTLINED BY THE AMERICAN SOCIETY FOR TESTING AND MATERIALS (ASTM).
5HSRUW5HSRUW(GLWRU

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

min

Intensity 0.0

2.5

5.0

7.5

10.0

12.5

15.0

17.5

20.0

22.5

25.0

27.5

30.0

0 50000 100000 150000 200000 250000

 1.054 / 1.137 / 1.407 / 1.593 / 1.670 / 

 1.730 / 1.902 / 2.040 / 2.109 / 2.280 / 2.363 / 2.418 / 2.566 / 2.667 / 2.855 / 2.950 / 3.035 / 3.136 / 3.214 / 3.343 / 3.421 / 3.540 / 3.635 / 3.773 / 3.863 / 3.967 / 4.070 / 4.149 / 4.335 / 4.509 / 4.584 / 4.694 / 4.750 / 4.901 / 5.022 / 5.166 / 5.366 / 5.510 / 5.610 / Decane (C10) 5.818 / 5.949 / 6.070 / 6.190 / 6.288 / 6.397 / 6.512 / 6.564 / 6.660 / 6.714 / 6.780 / 6.901 / 7.016 / 7.084 / 7.156 / 7.221 / 7.326 / 7.384 / 7.457 / 7.561 / 7.634 / 7.747 / 7.836 / 7.908 / 7.969 / 8.059 / 8.184 / 8.270 / 8.331 / 8.453 / 8.542 / 8.634 / 8.745 / 8.812 / 9.000 / 9.129 / 9.271 / 9.381 / 9.469 / 9.529 / 9.597 / 9.725 / 9.863 / 9.942 / 10.057 / 10.149 / 10.260 / 10.334 / 10.429 / 10.488 / 10.570 / 10.640 / 10.768 / 10.830 / 10.913 / 11.059 / 11.220 / 11.472 / 11.615 / 11.787 / 12.031 / 12.130 / 12.184 / 12.318 / 12.414 / 12.470 / 12.541 / 12.606 / 12.706 / 12.826 / 13.005 / 13.088 / 13.306 / 13.376 / 13.450 / 13.583 / 13.673 / 13.728 / 13.934 / 14.091 / 14.148 / 14.319 / 14.445 / 14.516 / 14.595 / 14.692 / 14.779 / 14.896 / 15.042 / 15.130 / 15.246 / 15.373 / 15.431 / 15.568 / 15.658 / 15.621 / 15.775 / 15.883 / 15.950 / o-terphenyl 16.056 / 16.118 / 16.191 / 16.341 / 16.460 / 16.573 / 16.667 / 16.814 / 16.894 / 16.987 / 17.144 / 17.313 / 17.452 / 17.528 / 17.644 / 17.796 / 17.963 / 18.087 / 18.144 / 18.226 / 18.292 / 18.436 / 18.558 / 18.723 / 18.924 / 18.986 / 19.083 / 19.198 / 19.272 / 19.329 / 19.473 / 19.627 / 19.786 / 19.849 / 19.928 / 20.077 / 20.180 / 20.244 / 20.372 / 20.431 / 20.488 / 20.634 / 20.798 / 20.870 / 20.952 / 21.027 / 21.131 / 21.218 / 21.313 / 21.422 / 21.538 / 21.594 / 21.705 / 21.795 / 21.845 / 21.966 / 22.068 / 22.188 / 22.368 / 22.426 / 22.604 / Octacosane (C28) 22.717 / 22.799 / 22.997 / 23.054 / 23.217 / 23.347 / 23.408 / 23.605 / 23.663 / 23.817 / 24.040 / 24.163 / 24.292 / 24.402 / 24.498 / 24.572 / 24.634 / 24.695 / 24.758 / 24.836 / 24.977 / 25.088 / 25.178 / 

 25.438 / 25.504 / 25.571 / 25.721 / 25.797 / 26.044 / 26.117 / 26.208 / 26.366 / 26.438 / 26.526 / 26.626 / 26.733 / 26.830 / 26.947 / 27.166 / 

 27.448 / 27.552 / 27.669 / 27.776 / 27.974 / 

 28.293 / 28.432 / 28.616 / 28.720 / 28.944 / 29.074 / 

 29.336 / 

 29.688 / 29 920 /
Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS 
	

	





	






























































 




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	Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

ATTACHMENT F: ENGINE MANUFACTURER’S SPECS 
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~TERPILLAR@

•

XQ230

SOUND ATTENUATED

DUAL VOLTAGE

50/60 Hz

Arrangement shown

with optional trailer

FEATURES

EMISSIONS

• EPA Tier 3 and CARS Emissions Certified for

non-road mobile applications at all 60 Hz and

50 Hz ratings

CAT C9 ATAAC DIESEL ENGINE

• Utilizes ACERT® Technology

• Reliable, rugged, durable design

• Field-proven in multiple applications

worldwide

• Four-stroke-cycle diesel engine combines

durability with minimum weight while

providing dependability and economy

• 50/60 Hz convertibility

CAT SR4B GENERATOR

• Designed to match performance and output

characteristics of diesel engines

• Permanent magnet excitation

• Segregated AC/DC, low voltage accessory box

provides single point access to accessory

connections

ENCLOSURE

• Made with 12-gauge steel

• Single point lifting eye

• Sound attenuated

• Convenient hand holds and steps for safe

operation

• Two coat polyester powder-coated finish

LEHE5329-03

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

• Certified 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.
RENTAL C~TERPILLAR®

FACTORY INSTALLED STANDARD AND OPTIONAL EQUIPMENT

STANDARD FEATURES

Air Inlet System Air cleaner, dual element

Turbocharger

Charging System Battery charger

Heavy duty charging alternator

Control Panel Generator controls and monitoring

Fuel tank monitoring

Engine controls and monitoring

Digital displays

Cooling System Fan and belt guards

Base mounted radiator

Air to air aftercooling

Distribution Panel Lockable doors

Load door safety switch, (trips breaker

upon door opening)

Individual bus bar connections

Circuit breaker with 24 VDC shunt trip

Remote start/stop contacts

Shore power connections

Enclosure Sound attenuated

12-gauge steel

Lockable doors

Separate vented battery compartment

Single point lifting

Exterior oil and water drains with interior valves

Hidden exterior fuel drain

Hand holds and steps

Powder coated finish

Fuel System Primary fuel filter/water separator

UL142 dual wall fUel tank 1667 L (440 gal)

Radiator-mounted fuel cooler

Generator Brushless, permanent magnet

Coastal corrosion protection

Shock mounted VR6 voltage regulator

Space heater

UL approved

Simultaneous three-phase 480/277 and

240/139 voltage

Mounting System Generator soft mounted to base

Base contains integral fuel tank

Skiddable structural steel design

110% oil and coolant spill containment

Starting System Electric starting motor

Battery set with disconnect switch

Jacket water heater with thermostat,

shut-off valves

OPTIONAL FEATURES

Trailer Full frame support

Independent tandem axle trailer frame

with tongue

Electric actuated hydraulic brakes

with rechargeable battery backup

breakaway system.

Overcenter mechanical parking brake

Full length fenders

Non-skid surface on steps

Heavy duty safety chains and

grab hooks

Reinforced 4540 kg (10,000 Ib) top

wind drop jack

LEHE5329-03 2
RENTAL

SPECIFICATIONS

CAT SR4B GENERATOR

Frame size 449

Type Permanent magnet brush less

Construction Single bearing, close coupled

Three-phase , 12 lead reconnectable

Insulation Class H with coastal insulation protection

IP rating 22

Alignment Pilot shaft

Voltage regulator 3-phase sensing with Volts-per-Hertz

Voltage regulation ± Yz% steady state/± Yz%

no load to full load

TIF Less than 50

THD Less than 5%

TECHNICAL DATA

C~TERPILLAR®

ENGINE

C9 ATAAC, 4-stroke-cycle watercooled diesel

Bore - mm (in) 112 (4.41)

Stroke - mm (in) 149 (5.87)

Displacement - L (cu in) , 8.8 (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, IP22 enclosure

Lockable hinged door

Enclosure mounted

Single location customer connector point

16 light alarm module with alarm horn

Electric fuel level gauge

Consult your Caterpillar dealer for available voltages.

X0230

Power Rating Standby TMIRef. Prime TMI Ref.

60 Hz ekW 230 DM8502 210 DM8512

50 Hz kVA 275 DM8504

Engine and Container Information

Engine model C9

Container dimensions see chart on page 6

Shipping Weight (Dry)

Unit with trailer kg (Ib) 6210 (13,690)

Unit without trailer kg (Ib) 4980 (10,980)

Maximum Fuel Capacity Weight

Unit with trailer kg (Ib) 7506 (16,550)

Unit without trailer kg (lb) 6278 (13,840)

Engine Lubricating Oil Capacity L(gal) 40 (10.55)

Engine Coolant Capacity with Radiator L(gal) 36 (9.5)

Fuel Tank Capacity L (gal) 1516 (400)

Fuel Consumption LJhr (gal/hr) 69.2 (18.3) 64.7 (17.1)

Fuel Consumption (75% Prime) LJhr (gal/hr) 50.6 (13,4)

Running lime @ 75% Prime hours 28

Sound Level

Standby dB(A) 74.72

No load @ 7 m (23 ft) dB(A) 70.20

Prime dB(A) 73.49

Ambient Capability Deg C (Deg F) 43 (109.4)

LEHE5329-03 3
RENTAL

RATING DEFINITIONS AND CONDITIONS

Meets or Exceeds International Specifications:

• NEMA MG1-32, IEC 60034, C8A, 98/37/EEC, 72/23/EEC,

UL 508, UL142,1803046/1,1808528, 89/336/EEC

Standby - Output available with varying load for the

duration of the interruption of the normal source power.

8tandby power in accordance with 1808528. Fuel stop power

in accordance with 1803046/1, A82789, DIN6271, and 885514.

Prime - Output available with varying load for an unlimited

time. Prime power in accordance with 1808528. 10% overload

power in accordance with 1803046/1, A82789, DIN6271, and

885514 available on request.

LEHE5329-03 4

C~TERPILLAR@

Ratings are based on 8AE J1349 standard conditions.

These ratings also apply at 1803046/1, DIN6271, and 885514

standard conditions.

Fuel rates are based on fuel oil of 35° API [@ 16° C (60° F)]

gravity having an LHV of 42780 kJ/kg (18,390 8tullb) when used

at 29° C (85° F) and weighing 838.9 g/liter (7.001 Ib/U.8. gal).

Additional ratings may be available for specific customer

requirements. Consult your Caterpillar representative for details.
RENTAL

DISTRIBUTION PANEL

C~TERPILLAR®

• CATERPILLAR.

i i

@-.

1

r

j

.. ---Q~-,-- ------------

LEHE5329-03 5

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 ('WI) ground stud

16. Dual voltage load connection bus board

[6.35 mm x 101.6 mm x 101.6 mm

(%" x 4" x 4") bus bars]
RENTAL

CONTAINER DIMENSIONS - TOP VIEW

. 901.3 [35.49]

272.8 [10.74]-+----t---1

2540.0 [100.00]

C~TERPILLAR@

1-----------6239.7[245.66]-------------l

CONTAINER DIMENSIONS - RIGHT SIDE VIEW

1---------6239.7[245.66]----------1

J-------4675.6[184.08)----- 1386.7 [54.60)

J------4361.6[171.72)------i

12383.7[93.84]

2240.4

2303.8[88.20~ 825.0

2865.1901.70) [71.85]

[112.81]

t-I-hrJ:."...l~===n==!~:--T"ir-+:~~~ "'''---LL.-k'/

415.4 [16.35]

Overall Dimensions

Package With Trailer

Length 4597.4 mm 181 in 6248.3 mm 246 in

Width 1498.6 mm 59in 2540.0 mm 100in

Height 2387.6 mm 94in 2882.8 mm 113.5 in

LEHE5329-03 6
Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

ATTACHMENT G: EMISSION CONTROL DEVICE 

MANUFACTURER’S SPECS 
CIiAaRaON

CIMARRON ENERGY 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.

H~m. Ol1lel: '·{5801 338-S"9S FAX 1·(5801 338-0835 P.O. BOll 1401$, Gu~mon, Oklahoma 739"2

Admlni.lr.ll.... OWel: 1-(<405) 928-7313 FAX 1-(405) 828·7380 P.O. SOl< 122110. Non",n, OI<Jaholt'la 73010
•

\

,

48" DlAx 302 SI~ HBGKT, 88 ORIFICES

EMISSION COHTROL DEVICE

.. >98% lVOC ORE, CERTIFIED USCPA <10 CFR

60, APPENDIX A, SOURCE EMMrsJONS TEST

METHODS REfERENCED. MEETS AI.l EPA&

CDPHE RfGUlATIONS. • DESTROYS OIIJCONDENSATE PRODUCTION

TANK VAPORS WI NO VISIBlE R.AME•

• EXCELLENT OPACITY AND SMOKELESS

OPfAATION. * RELIABlE AND CUSTOMIZABlf IGNITION. • VERY lOYi CAPITAl AND OPERATING COST. • EASY TO OPERATE AND MAlNTAIN. * WIll DESTROY UP TO 150 MCFD@l100Z/1rl

J

o

•

W1I1MUlll.I_JY:ltl!i'IIEY· 1_100.,_ ;

-- CIMARRON

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K:L-_I'I 1lO1~

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TYPICAL MANDAREE AREA 

SEVEN WELL PAD FACILITY PLOT PLAN 

Dakota-3 E&P Company, LLC 

FBIR, North Dakota 

NOT TO SCALE 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

Prod. H2O 

Recycle 

Pump 

Vent lines 

Chemicals 

(7)Wellheads 

Tank Vent line 

Utility 

Flare

 

LACT 

Gas to sales

Gas Meter

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

Prod. H2O 12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

Prod. H2O 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

Prod. H2O 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

Prod. H2O 12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

Prod. H2O 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

Enclosed 

Combustor

Recycle 

Pump 

Recycle 

Pump 

Recycle 

Pump 

Recycle 

Pump 

Recycle 

Pump 

Recycle 

Pump 

LACT 

Unit 

LACT 

Unit 

LACT 

Unit 

LACT 

Unit 

LACT 

Unit 

LACT 

Unit 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

12’d x 20’h 

400 bbl oil 

Valve

Valve

Valve

Valve

Valve

Valve

Valve

Recycle Line 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

Gas Meter 

(7) Gensets 

Genset

Oil Pipeline 

Water 

Pipeline 

24 bbl 

Diesel 

Gas Meter 

Legend 

Berms 

Water Line 

Crude Line 

Flowline 

Buried Recycle Lines 

Gas Sales Line 

Tank Vapor Line 

Flared Gas Line 
	



	










 
		


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

ATTACHMENT J: DIESEL TANK EPA TANKS 4.09D 

EMISSIONS SUMMARY 
TANKS 4.0.9d

Emissions Report - Detail Format 

Tank Indentification and Physical Characteristics

Identification

 User Identification: 1000 gallon diesel tank

 City: Williston

 State: North Dakota

 Company: Williams E&P, LLC

 Type of Tank: Horizontal Tank

 Description: 1,000 gallon diesel tank to fuel onsite diesel generators. Tank throughput is based on engine fuel consumption.

Tank Dimensions

 Shell Length (ft): 10.00

 Diameter (ft): 4.16

 Volume (gallons): 1,000.00

 Turnovers: 2,244.31

 Net Throughput(gal/yr): 2,244,312.00

 Is Tank Heated (y/n): N

 Is Tank Underground (y/n): N

Paint Characteristics

 Shell Color/Shade: Gray/Medium

 Shell Condition Good

Breather Vent Settings

 Vacuum Settings (psig): -0.03

 Pressure Settings (psig) 0.03

Meterological Data used in Emissions Calculations: Bismarck, North Dakota (Avg Atmospheric Pressure = 13.86 psia)

TANKS 4.0 Report Page 1 of 6

file://C:\Program Files\Tanks409d\summarydisplay.htm 9/29/2011
1000 gallon diesel tank - Horizontal Tank

Williston, North Dakota 

TANKS 4.0.9d

Emissions Report - Detail Format 

Liquid Contents of Storage Tank

Daily Liquid Surf. 

Temperature (deg F)

Liquid

Bulk

Temp Vapor Pressure (psia)

Vapor

Mol. 

Liquid

Mass 

Vapor

Mass Mol. Basis for Vapor Pressure

Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract. Fract. Weight Calculations

Distillate fuel oil no. 2 All 50.18 39.72 60.64 44.68 0.0045 0.0031 0.0067 130.0000 188.00 Option 1: VP50 = .0045 VP60 = .0065

TANKS 4.0 Report Page 2 of 6

file://C:\Program Files\Tanks409d\summarydisplay.htm 9/29/2011
1000 gallon diesel tank - Horizontal Tank

Williston, North Dakota 

TANKS 4.0.9d

Emissions Report - Detail Format 

Detail Calculations (AP-42)

Annual Emission Calcaulations

Standing Losses (lb): 0.2654

 Vapor Space Volume (cu ft): 86.5719

 Vapor Density (lb/cu ft): 0.0001

 Vapor Space Expansion Factor: 0.0780

 Vented Vapor Saturation Factor: 0.9995

Tank Vapor Space Volume:

 Vapor Space Volume (cu ft): 86.5719

 Tank Diameter (ft): 4.1600

 Effective Diameter (ft): 7.2797

 Vapor Space Outage (ft): 2.0800

 Tank Shell Length (ft): 10.0000

Vapor Density

 Vapor Density (lb/cu ft): 0.0001

 Vapor Molecular Weight (lb/lb-mole): 130.0000

 Vapor Pressure at Daily Average Liquid

 Surface Temperature (psia): 0.0045

 Daily Avg. Liquid Surface Temp. (deg. R): 509.8466

 Daily Average Ambient Temp. (deg. F): 41.5958

 Ideal Gas Constant R

 (psia cuft / (lb-mol-deg R)): 10.731

 Liquid Bulk Temperature (deg. R): 504.3458

 Tank Paint Solar Absorptance (Shell): 0.6800

 Daily Total Solar Insulation

 Factor (Btu/sqft day): 1,276.2450

Vapor Space Expansion Factor

 Vapor Space Expansion Factor: 0.0780

 Daily Vapor Temperature Range (deg. R): 41.8377

 Daily Vapor Pressure Range (psia): 0.0036

 Breather Vent Press. Setting Range(psia): 0.0600

 Vapor Pressure at Daily Average Liquid

 Surface Temperature (psia): 0.0045

 Vapor Pressure at Daily Minimum Liquid

 Surface Temperature (psia): 0.0031

 Vapor Pressure at Daily Maximum Liquid

 Surface Temperature (psia): 0.0067

 Daily Avg. Liquid Surface Temp. (deg R): 509.8466

 Daily Min. Liquid Surface Temp. (deg R): 499.3872

 Daily Max. Liquid Surface Temp. (deg R): 520.3060

 Daily Ambient Temp. Range (deg. R): 24.3583

Vented Vapor Saturation Factor

 Vented Vapor Saturation Factor: 0.9995

 Vapor Pressure at Daily Average Liquid:

 Surface Temperature (psia): 0.0045

 Vapor Space Outage (ft): 2.0800

Working Losses (lb): 5.6720

 Vapor Molecular Weight (lb/lb-mole): 130.0000

 Vapor Pressure at Daily Average Liquid

 Surface Temperature (psia): 0.0045

 Annual Net Throughput (gal/yr.): 2,244,312.0000

TANKS 4.0 Report Page 3 of 6

file://C:\Program Files\Tanks409d\summarydisplay.htm 9/29/2011
 Annual Turnovers: 2,244.3120

 Turnover Factor: 0.1800

 Tank Diameter (ft): 4.1600

 Working Loss Product Factor: 1.0000

Total Losses (lb): 5.9375

TANKS 4.0 Report Page 4 of 6

file://C:\Program Files\Tanks409d\summarydisplay.htm 9/29/2011
Emissions Report for: Annual 

1000 gallon diesel tank - Horizontal Tank

Williston, North Dakota 

TANKS 4.0.9d

Emissions Report - Detail Format 

Individual Tank Emission Totals

Losses(lbs)

Components Working Loss Breathing Loss Total Emissions

Distillate fuel oil no. 2 5.67 0.27 5.94

TANKS 4.0 Report Page 5 of 6

file://C:\Program Files\Tanks409d\summarydisplay.htm 9/29/2011
TANKS 4.0 Report Page 6 of 6

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