DAKOTA·3 t&P COMPANY, LLC

a subsldiar)' orWiliiams

1001 17'" Street, Suite 1200

Denver, CO 80202

303/527-3900

October 24, 20 II

Ms. Kathleen Paser

Minor NSR Permitting CoordiJlator

U.S. EPA, Region 8

1595 Wynkoop Avenue, 8P-AR

Denver, CO 80202-1129

Duplicate submittal provided via e-mail to:

paser.kathleen@epa.gov

Re: Synthetic Minor Source Permit Application for the Coyote Necklace 13-25H Pad

Dear Ms. Paser:

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

Source Permit Application for the Coyote Necklace 13-25H Pad. This application is being submitted in

accordance with the requirements ofthe August 29, 20 II 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

Dakota-] E&P Company, LLC

t~::PE Staff Environmental 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, NO 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

 Coyote Necklace 24-25H 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* 

 Mountrail 

11a. Latitude* 

47.8059284 

11b. Longitude* 

-102.5166491 

12a. Quarter Quarter Section* 

 SESE 

12b. Section* 

 13 

12c. Township* 

 150N 

12d. Range* 

 93W 
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 0.10 0.13 

PM10 0.10 0.13 

PM 2.5 0.10 0.13 

SOx 0.02 0.02 

NOx 5.75 6.39 

CO 46.78 50.28 

VOC 348.63 17.64 

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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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)
Van Hook Field 1000 BOPD wt%

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

* Project Setup Information *

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

Project File : Y:\Projects\Williams Exploration & Production WEP\WEP211324 Ft. Berthold

IR Well Work\E&P Tanks\Van Hook Field 1000 BOPD.ept

Flowsheet Selection : Oil Tank with Separator

Calculation Method : RVP Distillation

Control Efficiency : 100.0%

Known Separator Stream : Low Pressure Oil

Entering Air Composition : No

Filed Name : Van Hook

Well Name : Pennington 16-15H and Van Hook 16-14H Averages

Permit Number : Dakota-3 E&P Company, LLC

Date : 2010.09.24

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

* Data Input *

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

Separator Pressure : 52.00[psig]

Separator Temperature : 90.00[F]

Ambient Pressure : 13.70[psia]

Ambient Temperature : 50.00[F]

C10+ SG : 0.7970

C10+ MW : 233.494

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

 No. Component wt %

 1 H2S 0.0027

 2 O2 0.0000

 3 CO2 0.0038

 4 N2 0.0008

 5 C1 0.0261

 6 C2 0.3417

 7 C3 1.3723

 8 i-C4 0.3662

 9 n-C4 1.6928

 10 i-C5 0.6858

 11 n-C5 1.2496

 12 C6 1.4712

 13 C7 7.9550

 14 C8 19.2940

 15 C9 13.4810

 16 C10+ 49.4241

 17 Benzene 0.0470

 18 Toluene 0.1281

 19 E-Benzene 0.0586

 20 Xylenes 0.3912

 21 n-C6 1.5420

 22 224Trimethylp 0.4660

-- Sales Oil -----------------------------------------------------------------------------

Production Rate : 1000[bbl/day]

Days of Annual Operation : 365 [days/year]

API Gravity : 41.5

Reid Vapor Pressure : 6.20[psia]

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

* Calculation Results *

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

-- Emission Summary ----------------------------------------------------------------------

Item Uncontrolled Uncontrolled 

 [ton/yr] [lb/hr] 

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

Total HAPs 6.040 1.379 

Total HC 836.657 191.018 

VOCs, C2+ 823.270 187.961 

VOCs, C3+ 649.305 148.243 

Page 1
Van Hook Field 1000 BOPD wt%

 

Uncontrolled Recovery Info. 

 Vapor 41.5700 [MSCFD] 

 HC Vapor 41.3600 [MSCFD] 

 GOR 41.57 [SCF/bbl] 

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

No Component Uncontrolled Uncontrolled 

 [ton/yr] [lb/hr] 

1 H2S 1.343 0.307 

2 O2 0.000 0.000 

3 CO2 1.941 0.443 

4 N2 0.412 0.094 

5 C1 13.387 3.056 

6 C2 173.965 39.718 

7 C3 448.169 102.322 

8 i-C4 34.294 7.830 

9 n-C4 102.418 23.383 

10 i-C5 13.956 3.186 

11 n-C5 18.394 4.200 

12 C6 6.270 1.432 

13 C7 10.476 2.392 

14 C8 7.517 1.716 

15 C9 1.774 0.405 

16 C10+ 0.002 0.000 

17 Benzene 0.156 0.036 

18 Toluene 0.111 0.025 

19 E-Benzene 0.016 0.004 

20 Xylenes 0.090 0.021 

21 n-C6 5.168 1.180 

22 224Trimethylp 0.493 0.113 

 Total 840.352 191.861 

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

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

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

1 H2S 34.80 0.0027 0.0024 0.0001 0.1791 0.1609 0.1631 

2 O2 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 

3 CO2 44.01 0.0038 0.0026 0.0000 0.5796 0.1818 0.2307 

4 N2 28.01 0.0008 0.0001 0.0000 0.3282 0.0099 0.0490 

5 C1 16.04 0.0261 0.0112 0.0000 7.4009 0.7777 1.5911 

6 C2 30.07 0.3417 0.2811 0.0024 30.3262 19.3302 20.6806 

7 C3 44.10 1.3723 1.3000 0.5065 37.1767 55.5360 53.2811 

8 i-C4 58.12 0.3662 0.3594 0.3044 3.7640 4.1203 4.0766 

9 n-C4 58.12 1.6928 1.6719 1.5180 12.0581 12.1907 12.1744 

10 i-C5 72.15 0.6858 0.6836 0.6696 1.7610 1.6447 1.6590 

11 n-C5 72.15 1.2496 1.2474 1.2340 2.3296 2.1666 2.1866 

12 C6 86.16 1.4712 1.4725 1.4830 0.8134 0.7577 0.7645 

13 C7 100.20 7.9550 7.9683 8.0662 1.3546 1.2768 1.2865 

14 C8 114.23 19.2940 19.3310 19.6004 0.9553 0.9145 0.9195 

15 C9 128.28 13.4810 13.5078 13.7022 0.2134 0.2208 0.2201 

16 C10+ 233.49 49.4241 49.5238 50.2483 0.0000 0.0000 0.0000 

17 Benzene 78.11 0.0470 0.0471 0.0475 0.0197 0.0184 0.0186 

18 Toluene 92.13 0.1281 0.1283 0.1300 0.0137 0.0131 0.0132 

19 E-Benzene 106.17 0.0586 0.0587 0.0596 0.0020 0.0020 0.0018 

20 Xylenes 106.17 0.3912 0.3920 0.3976 0.0109 0.0106 0.0109 

21 n-C6 86.18 1.5420 1.5438 1.5575 0.6517 0.6091 0.6143 

22 224Trimethylp 114.24 0.4660 0.4668 0.4728 0.0617 0.0581 0.0587 

 

 MW 137.41 138.18 142.90 36.81 42.83 41.99 

 Stream Mole Ratio 1.0000 0.9924 0.9456 0.0076 0.0468 0.0544 

 Heating Value [BTU/SCF] 2105.43 2442.60 2395.38 

 Gas Gravity [Gas/Air] 1.27 1.48 1.45 

 Bubble Pt. @ 100F [psia] 29.55 23.39 7.57 

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

 RVP @ 100F [psia] 15.49 13.82 6.27 

 Spec. Gravity @ 100F 0.673 0.674 0.677 

Page 2
Emission estimates are based on using the E&P TANK V2.0 Model, RVP Distillation Column

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

of the oil with the given inputs listed below.

Inputs:

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

Separator: 52 psig, 90 degF

Flash Valve: 13.7 psia, 50 degF

Sales Oil: API Gravity 41.5, Reid Vapor Pressure 6.2 psia, 365 days/year

Outputs:

Oil Production Rates (bbl/day) (P) 0 50 100 300 1000

Emission (tons/yr)

Total HC 0 41.83255 83.6651 250.9953 836.651

VOCs, C3+ 0 32.46485 64.9297 194.7891 649.297

Total HAPs 0 0.302 0.604 1.812 6.04

VOC (C3+) Emission Factor: 0.6493 tpy/BOPD

HAP Emission Factor: 0.00604 tpy/BOPD

Oil Storage Tank Flashing Emissions Calculation Methodology

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

y = 0.00604x

R2 = 1.00000

y = 0.6493x

R2 = 1

-100

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.......... CRͲ5

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

S l Id tifi ti VAN HOOK 16 14 H CRUDE OIL

 EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

Sample Identification .................... VAN HOOK 16-14 H CRUDE OIL

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

Sample Pressure ......... 28 PSIG Sample Temperature.... 80 F

Type Sample ............... SPOT County...................... MONTRAIL

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

 Components Mole % Weight % Liq. Vol. %

Hydrogen Sulfide .......... 0.009 0.002 0.002

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

Carbon Dioxide ............ 0.010 0.003 0.003

Nitrogen ..................... 0.003 0.001 0.001

Methane ..................... 0 184 . 0 021 . 0 051 .

Ethane ....................... 1.152 0.241 0.501

Propane ..................... 3.568 1.096 1.600

isoͲButane .................. 0.778 0.315 0.414

nͲButane .................... 3.694 1.496 1.896

isoͲPentane ................ 1.242 0.624 0.739

nͲPentane ................... 2.270 1.141 1.339

Hexanes ..................... 2 276. 1 367. 1 523.

Heptanes .................... 10.418 7.274 7.823

Octanes ..................... 24.125 19.203 20.117

Nonanes ..................... 16.003 14.302 14.658

Decanes+ ................... 30.668 50.576 46.892

Benzene...................... 0.090 0.049 0.041

Toluene....................... 0.183 0.117 0.100

Ethylbenzene............... 0.047 0.035 0.030

Xylenes....................... 0.455 0.337 0.288

nͲHexane .................... 2.304 1.384 1.542

2,2,4ͲTrimethylpentane... 0.521 0.415 0.441

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

 Components Mole % Weight % Liq. Vol. %

2-Methylpentane 1.293 0.777 0.866

3-Methylpentane 3-Methylpentane 0 983 . 0 590 . 0 658 .

n-Hexane 2.304 1.384 1.542

2,2,4-Trimethylpentane 0.521 0.415 0.441

Benzene 0.090 0.049 0.041

Toluene 0.183 0.117 0.100

Ethylbenzene 0.047 0.035 0.030

m-Xylene 0.056 0.041 0.035

p-Xylene 0.291 0.216 0.184

o-Xylene 0.108 0.080 0.068

API GRAVITY AT 60/60 F, calculated........................................................................ 59.7

SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 0.7402

RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.7983

AVERAGE MOLECULAR WEIGHT .......................................................................... 143.505

AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 236.660

TRUE VAPOR PRESSURE AT 100 F PSIA calculated TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated................................................ 28 847 .

AVERAGE BOILING POINT, F, ................................................................................ 308.034

CUBIC FEET OF GAS / GALLON OF LIQUID, as Ideal Gas .......................................... 18.973

BTU / GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 122702.719

LBS / GALLON OF LIQUID, calculated ...................................................................... 6.171

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-5B 

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

Sample Identification................ VAN HOOK 16-14 H CRUDE OIL

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

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

Flowrate................... N/A County..................... MONTRAIL

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.............. 4.6 PSIG

TOTAL SULFUR CONTENT (ASTM D-5453), PPMW.................. PPMW 1,562.18

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 VanHook 16-14 C:\GCsolution\DRO\DRO Data\08-2010\08-01-2010\VanHook 16-14.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 / 1.307 / 1.405 / 1.552 / 1.669 / 

 1.729 / 1.901 / 2.038 / 2.108 / 2.280 / 2.361 / 2.417 / 2.564 / 

 2.666 / 2.854 / 2.948 / 3.034 / 3.135 / 3.210 / 3.301 / 3.420 / 3.538 / 3.638 / 3.772 / 3.857 / 3.966 / 4.069 / 4.147 / 4.333 / 4.508 / 4.582 / 4.693 / 4.899 / 5.021 / 5.165 / 5.364 / 5.509 / 5.608 / Decane (C10) 5.816 / 5.947 / 6.069 / 6.190 / 6.289 / 6.392 / 6.510 / 6.562 / 6.657 / 6.713 / 6.778 / 6.903 / 7.082 / 7.220 / 7.323 / 7.381 / 7.455 / 7.559 / 7.632 / 7.745 / 7.831 / 7.906 / 7.967 / 8.056 / 8.184 / 8.269 / 8.326 / 8.451 / 8.540 / 8.632 / 8.744 / 8.807 / 8.998 / 9.127 / 9.270 / 9.380 / 9.467 / 9.526 / 9.595 / 9.724 / 9.861 / 9.939 / 10.055 / 10.125 / 10.256 / 10.332 / 10.425 / 10.487 / 10.569 / 10.639 / 10.828 / 10.912 / 11.054 / 11.219 / 11.470 / 11.614 / 11.785 / 12.031 / 12.130 / 12.183 / 12.301 / 12.412 / 12.607 / 12.705 / 12.822 / 13.004 / 13.087 / 13.300 / 13.367 / 13.454 / 13.582 / 13.672 / 13.726 / 13.925 / 14.089 / 14.146 / 14.315 / 14.446 / 14.518 / 14.594 / 14.691 / 14.776 / 14.896 / 15.041 / 15.130 / 15.242 / 15.297 / 15.369 / 15.430 / 15.565 / 15.626 / 15.792 / 15.884 / 15.948 / o-terphenyl 16.062 / 16.183 / 16.346 / 16.458 / 16.570 / 16.667 / 16.813 / 16.896 / 16.987 / 17.134 / 17.231 / 17.310 / 17.450 / 17.528 / 17.642 / 17.765 / 17.957 / 18.048 / 18.140 / 18.222 / 18.289 / 18.436 / 18.589 / 18.722 / 18.914 / 18.981 / 19.082 / 19.197 / 19.332 / 19.465 / 19.623 / 19.673 / 19.783 / 19.850 / 19.928 / 19.997 / 20.067 / 20.181 / 20.252 / 20.368 / 20.446 / 20.500 / 20.633 / 20.762 / 20.792 / 20.873 / 21.032 / 21.137 / 21.213 / 21.310 / 21.411 / 21.473 / 21.528 / 21.626 / 21.725 / 21.801 / 21.880 / 21.970 / 22.051 / 22.098 / 22.215 / 22.368 / 22.429 / 22.605 / Octacosane (C28) 22.722 / 22.823 / 22.885 / 22.945 / 22.995 / 23.073 / 23.221 / 23.292 / 23.353 / 23.417 / 23.532 / 23.600 / 23.660 / 23.821 / 23.896 / 23.952 / 24.047 / 24.180 / 24.301 / 24.406 / 24.591 / 24.643 / 24.750 / 24.810 / 24.881 / 24.977 / 25.158 / 25.337 / 25.421 / 25.573 / 25.745 / 25.809 / 25.959 / 26.054 / 26.221 / 26.392 / 26.509 / 26.605 / 26.710 / 26.802 / 26.946 / 27.105 / 27.178 / 27.281 / 27.449 / 27.533 / 27.670 / 27.787 / 28.002 / 28.136 / 28.277 / 

 28.724 / 

 29.009 / 29.145 / 

 29.457 / 29.673 / 29.860 / 
Company .................... ZENERGY

Lab Number ................ CRͲ10330 Study Number.............. CRͲ4

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

S l Id tifi ti PENNINGTON 16 15 H CRUDE OIL

 EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

Sample Identification .................... PENNINGTON 16-15 H CRUDE OIL

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

Sample Pressure ......... 75 PSIG Sample Temperature...... 100 F

Type Sample ............... SPOT County........................ MONTRAIL

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

 Components Mole % Weight % Liq. Vol. %

Hydrogen Sulfide .......... 0.012 0.003 0.003

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

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

Nitrogen ..................... 0.004 0.001 0.001

Methane ..................... 0 270 . 0 032 . 0 078 .

Ethane ....................... 2.018 0.448 0.920

Propane ..................... 5.113 1.663 2.400

isoͲButane .................. 0.980 0.420 0.546

nͲButane .................... 4.432 1.900 2.381

isoͲPentane ................ 1.409 0.750 0.878

nͲPentane ................... 2.562 1.364 1.582

Hexanes ..................... 2 488. 1 582. 1 743.

Heptanes .................... 11.732 8.673 9.222

Octanes ..................... 22.998 19.381 20.074

Nonanes ..................... 13.316 12.600 12.767

Decanes+ ................... 28.387 48.236 44.369

Benzene...................... 0.078 0.045 0.037

Toluene....................... 0.204 0.139 0.116

Ethylbenzene............... 0.107 0.084 0.070

Xylenes....................... 0.573 0.449 0.379

nͲHexane .................... 2.688 1.709 1.883

2,2,4ͲTrimethylpentane... 0.616 0.519 0.545

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

 Components Mole % Weight % Liq. Vol. %

2-Methylpentane 1.398 0.889 0.979

3-Methylpentane 3-Methylpentane 1 090 . 0 693 . 0 764 .

n-Hexane 2.688 1.709 1.883

2,2,4-Trimethylpentane 0.616 0.519 0.545

Benzene 0.078 0.045 0.037

Toluene 0.204 0.139 0.116

Ethylbenzene 0.107 0.084 0.070

m-Xylene 0.067 0.053 0.045

p-Xylene 0.386 0.302 0.255

o-Xylene 0.120 0.094 0.079

API GRAVITY AT 60/60 F, calculated........................................................................ 61.9

SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 0.7318

RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.7956

AVERAGE MOLECULAR WEIGHT .......................................................................... 135.548

AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 230.327

TRUE VAPOR PRESSURE AT 100 F PSIA calculated TRUE VAPOR PRESSURE AT 100 F, PSIA, calculated................................................ 43 649 .

AVERAGE BOILING POINT, F, ................................................................................ 283.928

CUBIC FEET OF GAS / GALLON OF LIQUID, as Ideal Gas .......................................... 19.480

BTU / GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 121815.044

LBS / GALLON OF LIQUID, calculated ...................................................................... 6.102

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-4B 

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

Sample Identification................ PENNINGTON 16-15 H CRUDE OIL

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

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

Flowrate................... N/A County..................... MONTRAIL

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

1-QUART 

BOTTLE

TEST PERFORMED RESULTS

API GRAVITY AT 60/60 F (ASTM D-287), observed...................... / ( ), 41.8

SPECIFIC GRAVITY AT 60/60 F (ASTM D-1657), calculated.......... 0.8165

REID VAPOR PRESSURE (ASTM D-323), PSIG AT 100 F.............. 7.8 PSIG

TOTAL SULFUR CONTENT (ASTM D-5453), PPMW.................. PPMW 1,435.60

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).
Report(Report Editor)

Chromatogram Pennington 16-15H C:\GCsolution\DRO\DRO Data\08-2010\08-01-2010\Pennington 16-15H.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

 1.054 / 1.137 / 1.405 / 1.552 / 

 1.669 / 1.730 / 1.901 / 2.039 / 2.109 / 2.281 / 2.362 / 2.418 / 2.564 / 

 2.667 / 2.854 / 2.949 / 3.035 / 3.135 / 3.210 / 3.301 / 3.421 / 3.539 / 3.637 / 3.740 / 3.857 / 3.967 / 4.069 / 4.148 / 4.334 / 4.509 / 4.583 / 4.693 / 4.901 / 5.022 / 5.166 / 5.365 / 5.512 / 5.609 / Decane (C10) 5.819 / 5.949 / 6.070 / 6.136 / 6.191 / 6.292 / 6.395 / 6.466 / 6.659 / 6.714 / 6.779 / 6.905 / 7.083 / 7.154 / 7.221 / 7.325 / 7.457 / 7.560 / 7.634 / 7.745 / 7.833 / 7.907 / 7.967 / 8.057 / 8.184 / 8.270 / 8.327 / 8.452 / 8.541 / 8.633 / 8.743 / 8.809 / 8.999 / 9.128 / 9.270 / 9.380 / 9.467 / 9.529 / 9.595 / 9.724 / 9.863 / 9.941 / 10.053 / 10.147 / 10.259 / 10.331 / 10.427 / 10.487 / 10.570 / 10.638 / 10.768 / 10.828 / 10.912 / 11.059 / 11.265 / 11.222 / 11.470 / 11.614 / 11.786 / 12.030 / 12.130 / 12.186 / 12.300 / 12.416 / 12.469 / 12.604 / 12.703 / 12.823 / 13.006 / 13.087 / 13.304 / 13.372 / 13.447 / 13.583 / 13.673 / 13.730 / 13.932 / 14.090 / 14.147 / 14.322 / 14.440 / 14.518 / 14.594 / 14.692 / 14.776 / 14.903 / 15.041 / 15.131 / 15.243 / 15.302 / 15.370 / 15.432 / 15.570 / 15.626 / 15.788 / 15.885 / 15.948 / o-terphenyl 16.044 / 16.183 / 16.344 / 16.460 / 16.573 / 16.674 / 16.814 / 16.895 / 16.970 / 17.137 / 17.329 / 17.446 / 17.535 / 17.643 / 17.802 / 17.961 / 18.057 / 18.128 / 18.224 / 18.286 / 18.435 / 18.595 / 18.722 / 18.918 / 18.983 / 19.078 / 19.197 / 19.331 / 19.480 / 19.598 / 19.651 / 19.702 / 19.783 / 19.851 / 19.927 / 20.074 / 20.181 / 20.361 / 20.440 / 20.517 / 20.634 / 20.795 / 20.874 / 21.027 / 21.136 / 21.309 / 21.400 / 21.541 / 21.724 / 21.789 / 21.888 / 21.969 / 22.076 / 22.183 / 22.375 / 22.436 / 22.605 / Octacosane (C28) 22.719 / 22.799 / 22.998 / 23.056 / 23.106 / 23.220 / 23.422 / 23.502 / 23.624 / 23.677 / 23.815 / 23.917 / 23.968 / 24.038 / 24.175 / 24.300 / 24.404 / 24.615 / 24.704 / 24.762 / 24.824 / 24.896 / 24.973 / 25.070 / 25.139 / 25.197 / 25.259 / 25.329 / 25.454 / 25.573 / 25.720 / 25.795 / 25.869 / 25.956 / 26.069 / 26.222 / 26.421 / 26.547 / 26.638 / 26.744 / 26.842 / 26.947 / 27.166 / 27.295 / 27.437 / 27.581 / 27.764 / 27.902 / 28.049 / 28.197 / 28.360 / 28.528 / 
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

""-.,

-....._A$>UOXII, -=n:lII1'IIl Off1

K:L-_I'I 1lO1~

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.........._....

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TYPICAL VAN HOOK AREA 

ONE WELL PAD FACILITY PLOT PLAN 

Dakota-3 E&P Company, LLC 

FBIR, North Dakota 

NOT TO SCALE 

Chemicals 

(1)Wellhead 

Tank Vent line 

Utility Flare

Gas to sales

Gas Meter

12’d x 20’h 

400 bbl oil 

Enclosed 

Combustor

Recycle 

Pump 

12’d x 20’h 

400 bbl oil 

Valve

Recycle Line 

6’d x 20’h 

vertical treater 

Separator 30” d 

by 10’ h 

Gas Meter 

(1) Genset 

Genset

12’d x 20’h 

400 bbl 

Prod. H2O 

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 

24 bbl 

Diesel 

Oil Getty Box 

Water Getty Box 

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