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.kath leen@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 of the 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 17 th 

### 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 17 th 

### Street, Suite 1200 Denver, CO 80202

Email Address: JoDell.Mizoue@Williams.com

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

**Operato r**  **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 C ontact:**  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, PM 10 

### , PM 2.5 

### , 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 (H 2 

### SO 4 

### ), hydrogen sulfide (H 2 

### S), 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 PM 10 

### - Particulate Matter less than 10 microns in size PM 2.5 

### - 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 H 2 

### SO 4 

### - Sulfuric Acid Mist H 2 

### S - Hydrogen Sulfide TRS - Total Reduced Sulfur RSC - Reduced Sulfur Compounds **PM** 

### 0.10 **0.13**
**PM 10**  

### 0.10 **0.13**
**PM 2.5**  

### 0.10 **0.13**

**SO x**  

### 0.02 **0.02**

**NO x**  

### 5.75 **6.39**
**CO** 

### 46.78 **50.28**
**VOC** 

### 348.63 **17.64**

**Pb** 

### Negligible **Negligible**
**Fluorides** 

### Negligible **Negligible**

**H 2**  

### SO **4** 

### Negligible **Negligible**

**H 2**  

### S 

### 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**

**PM 10**  

### N/A **N/A N/A**  **N/A**

**PM 2.5**  

### N/A **N/A N/A**  **N/A**

**SO x**  

### N/A **N/A N/A**  **N/A**

**NO x**  

### 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**

**NH 3**  

### N/A **N/A N/A**  **N/A**

**Fluorides** 

### N/A **N/A N/A**  **N/A**

**H 2**  

### SO **4** 

### N/A **N/A N/A**  **N/A**

**H 2**  

### S 

### N/A **N/A N/A**  **N/A**
**TRS** 

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

### N/A **N/A N/A**  **N/A**

PM - Particulate Matter PM 10 

### - Particulate Matter less than 10 microns in size PM 2.5 

### - 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 NH 3 

### - Ammonia Fluorides - Gaseous and particulates H 2 

### SO 4 

### - Sulfuric Acid Mist H 2 

### S - Hydrogen Sulfide TRS - Total Reduced Sulfur RSC - Reduced Sulfur CompoundsPage 7 of 15 

# Instructions

**U se 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 FederalMinor 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.



###  L 

### ist 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**

 E stimates of Current Actual Emissions, Current Allowable Emissions, Post-Change Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants: particulate matter, PM 10 

### , PM 2.5 

### , sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead compounds, ammonia (NH 3 

### ), fluorides (gaseous and particulate), sulfuric acid mist (H 2 

### SO 4 

### ), hydrogen sulfide (H 2 

### S), 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 anyPage 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 4 th 

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

Gail Tonnesen Region 8 Modeling Lead Tonnesen.gail@epa.gov 303-312- 6113Page 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.ht m . 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/m 3**  

### ) **Class I Area SIL (ug/m**  **3** 

### )

SO 2 

### 1 hr 3 ppb or 7.8 ug/m 3 

### (interim) ---- 3 hr 25 1.0 24 hr 5 0.2 Annual 1 0.08


### PM 2.5 

### 24 hr 0.07 1.2 Annual 0.06 0.3


### PM 10 

### 24 hr 5 0.2 Annual 1 0.08 

### NO 2 

### 1 hr 4 ppb or 7.5 ug/m 3 

### (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.



##  **E SA** 

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.

T o 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.



##  **N HPA** 

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=n atreghome

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 1Van 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 2Emission 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 R 2 = 1.00000 y = 0.6493x R 2 = 1

-100 0 100 200 300 400 500 600 700

0 500 1000 1500tons/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

................ CR

Ͳ 10330 Study Number.......... CR

Ͳ 5 Date Sampled

.............. 7

Ͳ 15

Ͳ 2010 Date Tested............. 7

Ͳ 23

Ͳ 2010

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

### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

Samp l e I d enti f ication

.................... V AN H OO K 16-14 H C RUDE O IL



### Sample Location .......... MONTANA. Sample Pressure ......... 28 PSIG Sample Temperature.... 80 F Type Sample ............... SPOT County...................... MONTRAIL Test method ................ 

### GPA

Ͳ 2286 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 

### iso

Ͳ Butane

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



### n

Ͳ Butane

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

### iso

Ͳ Pentane

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



### n

Ͳ Pentane

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

### H 2 276 1 367 1 523 

### exanes

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

### 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



### n

Ͳ Hexane

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

### 2,2,4

Ͳ Trimethylpentane... 0.521 0.415 0.441


### TOTALS

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



### Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.293 0.777 0.866 3-Methylpentane 0 983 0 590 0 658 3

- Methylpentane

. . . n-Hexane 2.304 1.384 1.542 2,2,4-Trimethylpentane 0.521 0.415 0.441
Benzene 0.090 0.049 0.041
Toluene 0.183 0.117 0.100 Ethylbenzene 0.047 0.035 0.030 m-Xylene 0.056 0.041 0.035 p-Xylene 0.291 0.216 0.184 o-Xylene 0.108 0.080 0.068

API GRAVITY AT 60/60 F, calculated........................................................................ 59.7 SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 0.7402 RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.7983 AVERAGE MOLECULAR WEIGHT .......................................................................... 143.505 AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 236.660 TRUE VAPOR PRESSURE AT 100 F PSIA calculated 28 847 TRUE VAPOR PRESSURE AT 100 F

, PSIA

, calculated

................................................ . 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 b CR 10330 St d N b a umer............. CR-10330 Study Number............ 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

A PI 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.................. 1,562.18 PPMW

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

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

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

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

NOTATION : 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 1min 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

................ CR

Ͳ 10330 Study Number.............. CR

Ͳ 4 Date Sampled

.............. 7

Ͳ 15

Ͳ 2010 Date Tested................. 7

Ͳ 23

Ͳ 2010

S l Id tifi ti PENNINGTON 16 15 H CRUDE OIL 

### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

Samp l e I d enti f ication

.................... PENNIN G T O N 16-15 H C RUDE O IL



### Sample Location .......... MONTANA. Sample Pressure ......... 75 PSIG Sample Temperature...... 100 F Type Sample ............... SPOT County........................ MONTRAIL Test method ................ 

### GPA

Ͳ 2286 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 

### iso

Ͳ Butane

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



### n

Ͳ Butane

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

### iso

Ͳ Pentane

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



### n

Ͳ Pentane

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

### H 2 488 1 582 1 743 

### exanes

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

### 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



### n

Ͳ Hexane

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

### 2,2,4

Ͳ Trimethylpentane... 0.616 0.519 0.545


### TOTALS

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



### Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.398 0.889 0.979 3-Methylpentane 1 090 0 693 0 764 3

- Methylpentane

. . . 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 43 649 TRUE VAPOR PRESSURE AT 100 F

, PSIA

, calculated

................................................ . 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 b CR 10330 St d N b a umer............. CR-10330 Study Number............ 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

A PI 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.................. 1,435.60 PPMW

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

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

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

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

NOTATION : 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 1min 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 / 11.222 / 11.265 / 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

• UL 142 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 UL 142 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, UL 142,1803046/1,1808528, 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 

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..**---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 6Dakota-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" DlA x 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 

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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 **E MISSIONS 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) 

### Page 1 of 6 TANKS 4.0 Report

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

### 1000 gallon diesel tank - Horizontal Tank Williston, North Dakota 

### T ANKS 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 

### Page 2 of 6 TANKS 4.0 Report

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

### 1000 gallon diesel tank - Horizontal Tank Williston, North Dakota 

### T ANKS 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 

### Page 3 of 6 TANKS 4.0 Report

9/29/2011 file://C:\Program Files\Tanks409d\summarydisplay.htmAnnual Turnovers: 2,244.3120 Turnover Factor: 0.1800 Tank Diameter (ft): 4.1600 Working Loss Product Factor: 1.0000

Total Losses (lb): 5.9375 

### Page 4 of 6 TANKS 4.0 Report

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

### Emissions Report for: Annual

1000 gallon diesel tank - Horizontal Tank Williston, North Dakota 

### T ANKS 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 

### Page 5 of 6 TANKS 4.0 Report

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

### Page 6 of 6 TANKS 4.0 Report

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