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

a subsidia'1' of Williams 100 I 17 th Streel, Suile 1200 Denver, CO 80202 303/527-3900



### December 21, 20 II

Ms. Kathleen Paser Minor NSR Permitting Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129 Duplicate submittal provided via e-mail to: r8airpermitting@epa.gov

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

Dear Ms. Paser:

Dakota-3 E&P Company, LLC (Dakota-3) a subsidiaty of Williams is submitting this Synthetic Minor Source Permit Application for the Maggie Old Dog 19-18H Pad. This application is being submitted in accordance with the requirements of the August 29, 2011 Consent Agreement, regarding compliance with the Federal Minor New Source Review Rule.

Do not hesitate to contact me with any questions either by phone at 303-606-4056, or bye-mail at JoDell.Mizoue@Williams.com.

Sincerely,



### Williams 

# Dil1tPUUy,

LLC--"-.-..--

__

JoDell Mizoue, P.E 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, ND 58763-9404 (letter Only)

### UNITED STATES ENVIRONMENTAL PROTECTION AGENCY **Region 8 Air Program FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY** 


## Check List – Application for New Construction (Form NEW) **Please check all that apply to show how you are using this form**



# • **Proposed Construction of a New Facility**


# o **Proposed Construction of New Equipment at an Existing Facility**


# o **Proposed Modification of an Existing Facility**


# o **Other – Please Explain Use of this information request form is voluntary and not yet approved**  **by the Office of Management and Budget.** The following is a check list of the type of information that Region 8 will use to process information on your proposed project. While submittal of this form is not required, it does offer details on the information we will use to complete your requested approval and providing the information requested may help expedite the process. Use of application forms for this program is currently under Office of Management and Budget review and these information request forms will be replaced/updated after that review is completed.



### Please submit information to **following two entities:**
Minor NSR Permitting Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P-AR Denver, CO 80202-1129 The Tribal Environmental Contact for the specific reservation:
If you need assistance in identifying the appropriate Tribal Environmental Contact and address, please contact the EPA Region 8 Tribal Air Coordinator:
Alexis North, EPA Region 8 Tribal Air Coordinator 303-312-7005 north.alexis@epa.gov



### A. GENERAL FACILITY INFORMATION 1. (a) **Company Name** Dakota-3 E&P Company, LLC

(b) **Operator Name** Dakota-3 E&P Company, LLC 2. **Facility Name** Maggie Old Dog 19-18H Pad

3. Type of Operation Oil and Gas Production 4. Portable Source? Yes No 5. Temporary Source? Yes No
6. NAICS Code 213111 7. SIC Code 1311 8. Physical Address: 1001 17 th 

### Street, Suite 1200 Denver, CO 80202

9. Reservation* FBIR 10. County* Dunn 11a. Latitude* 47.7916087 11b. Longitude* -102.6347529

12a. Quarter Quarter Section 

### * SESW 12b. Section* 19 12c. Township* T150N 12d. Range* R93W

### B. PREVIOUS PERMIT ACTIONS (Provide information in this format for each permit that has been issued to this facility. Provide as an attachment if additional space is necessary)
This section of the permit application is not applicable. This application is for a new facility for which no previous permit actions have been taken.

Facility Name on the Permit N/A

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

Date of the Permit Action N/A

### C. CONTACT INFORMATION **Company Contact:** JoDell Mizoue Title: Staff Environmental Specialist Mailing Address: 1001 17 th 

### 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, 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** 

### 0.53 **0.64**

**PM 10**  

### 0.53 **0.64**

**PM 2.5**  

### 0.53 **0.64**

**SO x**  

### 0.16 **0.16**

**NO x**  

### 35.52 **37.70**

**CO** 

### 67.50 **79.38**

**VOC** 

### 1278.69 **50.66**

**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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#  Facility Information Maggie Old Dog 19-18H Pad Associated Wells: Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7 Name of the facility and the well number. Not Producing Yet Approximate first date of production or the date of modification of the facility.
Production Data Description BOPD 3807 Average daily production in barrels of oil per day (BOPD), based on the predicted first 30 days of production. Mscfd 2646 Average daily production of gas in Mscf per day, based on the predicted first 30 days of production. Decline Factor 0.505 Expected decline factor for the first year of operation. Based on data from previously producing wells in th e same field and formation. Adjusted BOPD 1924 This is the calculated BOPD expected to be produced using the above entered decline factor. Adjusted Produced Gas (Mscfd) 1337 This is the calculated mcfd of gas the well is expected to produce using the above entered decline factor.

Oil/Condensate Tank Data Description Flash Gas Method: Process Simulator Use the drop down menu to choose the appropriate flash gas method. Process Simulator Estimated scf/bbl 39.1 The scf/bbl from direct measurement or representative sample. Based on representative E&P Tank Emission Summary Ou tput. Estimated Tank Vapors (scfd) 75216.551 This is the estimated scfd of tank vapors based on the following: adjusted BOPD multiplied by the scf/bbl entered on Line 9. Lower Heating Value 2338.03 Lower heating value (Btu/scf) of tank vapors. Based on representative E&P Tank Emission Summary Ou tput. Molecular Weight 40.93 Molecular weight of the tank vapors in pounds per pound-mole (lb/lb-mole). Based on representative E&P Tank Emission Summary Ou tput. VOC% 73.87712 VOC weight fraction of the tank vapor gas (C3+). Based on representative E&P Tank Emission Summary Ou tput. VOC TPY/BOPD Emission Factor 0.6514 Based on representative E&P Tank Emission Summary Output. (Summary Output creates a linear relationship between TPY and BOPD) HAP% 0.7286263 HAP weight fraction of the tank vapor gas. Based on representative E&P Tank Emission Summary Ou tput. HAP TPY/BOPD Emission Factor 0.0056 Based on representative E&P Tank Emission Summary Output. (Summary Output creates a linear relationship between TPY and BOPD) CO2% 0.29% CO2 weight fraction of the tank vapor gas. Based on representative E&P Tank Emission Summary O utput. CH4% 2.15% CH4 weight fraction of the tank vapor gas. Based on representative E&P Tank Emission Summary Ou tput. H 2 S weight % 0.09% H 2 S weight percent of the tank vapor gas. Based on representative E&P Tank Emission Summary Ou tput.
H 2 S mole % 0.11% H 2 S mole percent of the tank vapor gas. Based on representative E&P Tank Emission Summary Ou tput. Enclosed Smokeless Combustor Use the drop down menu to choose the appropriate emission control type. Control Destruction Efficiency 98% Control efficiency of any applicable controls. This is a fixed number based on control type. RED = No input required. This is a calculated value. Input Data 

# Dakota-3 E&P Company, LLC

GREEN = Requires inputFacility Information Maggie Old Dog 19-18H Pad Associated Wells: Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7 Name of the facility and the well number. RED = No input required. This is a calculated value. Input Data 

# Dakota-3 E&P Company, LLC

GREEN = Requires input

Treater Gas Data Description Btu/scf 1700.3866 Btu/scf of wellstream gas. (From representative field gas analysis) Molecular Weight 29.646857 Average molecular weight of the wellstream gas in lb/lb-mole. (From representative field gas analysis) Specific Gravity 1.0236429 If necessary to convert specific gravity to molecular weight, enter the specific gravity of the wellstream gas. (From representative field gas analysis) Average Molecular Weight 29.647 (From representative field gas analyses) VOC% 45.94% VOC weight fraction of the wellstream gas (Note: Weight%, not Mole%). (From representative field gas analysis) HAP% 1.28% HAP weight fraction of the wellstream gas. (Note: Weight%, not Mole%). (From representative field gas analysis) CO2% 0.863% CO2 weight fraction of the wellstream gas. (Note: Weight%, not Mole%). (From representative field gas analysis) CH4% 25.747% CH4 weight fraction of the wellstream gas. (Note: Weight%, not Mole%). (From representative field gas analysis) H 2 S weight % 0.000% H 2 S weight percent of the wellstream gas. (From representative field gas analysis)
H 2 S mole % 0.000% H 2 S mole percent of the wellstream gas. (From representative field gas analysis) Connected to sales line Use the drop down menu to choose the appropriate emission control type. Control/Capture Efficiency 100% If routed to pipeline, assumed 100% capture of gas. If flared, control efficiency of any applicable controls (combustor, pit flare, utility flare, etc).
Treater Burner(s) Description Total Btu/hr 5250000 Total burner rating for the heater treater burner(s) in btu/hr. If there are multiple burners, add the total heat input together. Hours of Operation 8,760 The burner(s) is/are assumed to operate 8,760 hours per year.
Truck Loading Description Oil is sold through LACT Use the drop down menu to choose the appropriate oil sales method. If oil is sold through a LACT, no input values are required in Lines 30-35. Submerged loading: dedicated normal service 0.6 Use the drop down list to choose the appropriate mode of operation. The saturation factor will automatically be selected based on mode of operation. Molecular Weight 40.93 Molecular weight of tank vapors in lb/lb-mole. Assumed same molecular weight as flashing emissions from representative E&P Tanks data. Vapor Pressure 2.30 True vapor pressure of liquid loaded, pounds per square inch absolute (psia) If no site specific data is available, please refer to Table 2 on Truck Loading tab. Temperature 50.00 Temperature of bulk liquid loaded in Fahrenheit. If no site specific data is available, use an estimated average annual temperature. Load Rate (bbl/hr) 180 Load rate of liquid loaded in barrels per hour. Load Time (hrs) 1.00 The time it takes to loadout one load (hrs). Pneumatic Pumps and Contollers (None) Description
Glycol Dehydrator (None) DescriptionFacility: Maggie Old Dog 19-18H Pad Associated Wells: Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7

VOC HAP NOx PM PM10 PM2.5 CO H 2 S SO 2 HCHO Oil/Condensate Tanks 1253.10 10.80 N/A N/A N/A N/A N/A N/A N/A Negligible Casing Head Gas 17.54 0.49 2.82 0.19 0.19 0.19 15.35 NA 0.00 0.00 Treater Burner 0.12 0.04 2.25 0.17 0.17 0.17 1.89 N/A 0.01 Negligible RICE Engine 7.93 1.19E-01 30.44 0.18 0.18 0.18 50.26 N/A 1.45E-01 0.12 Truck Loading N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible Fuel Storage Tank Negligible Negligible N/A N/A N/A N/A N/A N/A N/A N/A Pneumatic Pump N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible Pneumatic Controllers N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible Glycol Dehydrator N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

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

VOC HAP NOx PM PM10 PM2.5 CO H 2 S SO 2 HCHO Oil/Condensate Tanks 25.06 0.22 2.18 0.10 0.10 0.10 11.87 N/A N/A Negligible Casing Head Gas 17.54 0.49 2.82 0.19 0.19 0.19 15.35 0.00 0.00 0.00 Treater Burner 0.12 0.04 2.25 0.17 0.17 0.17 1.89 N/A 0.01 Negligible RICE Engine 7.93 1.19E-01 30.44 0.18 0.18 0.18 50.26 N/A 1.45E-01 0.12 Truck Loading N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible Fuel Storage Tank Negligible Negligible N/A N/A N/A N/A N/A N/A N/A N/A Pneumatic Pump N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible Pneumatic Controllers N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible Glycol Dehydrator N/A N/A N/A N/A N/A N/A N/A N/A N/A Negligible

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

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

Criteria Pollutants a 

# Dakota-3 E&P Company, LLC

Allowable Potential to Emit 

## Emission Summary

Uncontrolled Potential to EmitFacility: Maggie Old Dog 19-18H Pad Associated Wells: Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7 

# Dakota-3 E&P Company, LLC

CO 2 CH 4 N 2 O CO 2 CH 4 N 2 O Oil/Condensate Tanks N/A 31.86 N/A 1651.47 0.00 0.03 Casing Head Gas 2944.43 9.83 0.00 2944.43 9.83 0.00 Treater Burner 2705.29 0.15 0.03 2705.29 0.15 0.03 RICE Engine 2.65E+02 0.40 0.08 2.65E+02 0.40 0.08 Truck Loading 0.00 0.00 N/A 0.00 0.00 N/A Fuel Storage Tank N/A N/A N/A N/A N/A N/A Pneumatic Pump N/A N/A N/A N/A N/A N/A Pneumatic Controllers N/A N/A N/A N/A N/A N/A Glycol Dehydrator N/A N/A N/A N/A N/A N/A

Totals (TPY) 5914.67 42.24 0.11 7566.14 10.38 0.15

GHG Mass Emissions (tpy): 5957.02 GHG Mass Emissions (tpy): 7576.67 CO2e (tpy): 6836.99 CO2e (tpy): 7829.24 Applicable to the Tailoring Rule?: No

b Hydrofluorocarbons (HFCs), Perfluorocarbons (PFCs), and Sulfur Hexafluorides (SF6) emissions are not created from O&G production operations. Actual Greenhouse Gases b Potential To Emit Greenhouse Gases bBOPD

scf/day

Btu/scf

lb/lb-mole

tpy/bopd

HAPs: Benzene wt Fraction Toluene wt Fraction E-Benzene wt Fraction Xylene wt Fraction n-Hexane wt Fraction 2,2,4-Trimethylpentane wt Fraction

HAP Emission Factor tpy/bopd

98% destruction efficiency of the VOC gas. 0.0203%

0.0021% 0.0110%

0.6343% 0.0116%

0.0493%

CH4 wt Fraction 0.006

Controlled emissions are calculated based on a 0.29%

2.15% CO2 wt Fraction 

# Dakota-3 E&P Company, LLC

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

## Tanks

Flare Gas Volume 75,217 Oil Production 1924

0.651 Lower Heating Value 2338.03

Molecular Weight 40.93

VOC wt Fraction 73.88%

VOC Emission Factor

# Dakota-3 E&P Company, LLC

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

## Tanks

Uncontrolled VOCs (PTE):
DRE Using E&P Tanks Run: 0.651 x 1923.7 x 0% = 1253.10 TPY



### Controlled VOCs (Allowable):
DRE Using E&P Tanks Run: 0.651 x 1923.7 x 98% = 25.06 TPY



### Uncontrolled HAPs (PTE): Using E&P Tanks Run: wt% DRE TPY Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.02% x 0% = 0.07 lb/hr 0.30 E-Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.00% x 0% = 0.01 lb/hr 0.03

Toluene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 0% = 0.04 lb/hr 0.16 n-Hexane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.63% x 0% = 2.15 lb/hr 9.40

Xylene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 0% = 0.04 lb/hr 0.17 2,2,4-Trimethylpentane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.05% x 0% = 0.17 lb/hr 0.73

Uncontrolled TOTAL HAPS (TPY) 10.80



### Controlled HAPs (Allowable):
Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.02% x 98% = 0.00 lb/hr 0.01 E-Benzene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.00% x 98% = 0.00 lb/hr 0.00

Toluene 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00 n-Hexane 3,134 scf/hr x x 1/379 scf/lb-mole x 40.93 lb/lb-mol x 0.63% x 98% = 0.04 lb/hr 0.19

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

Controlled TOTAL HAPS (TPY) 0.22 BOPD

TPY VOC/BOPD TPY VOC/BOPD 

## CRITERIA POLLUTANT EMISSIONS a

BOPD

= =

=

=

=

=

=

=

= =

= =

=

=

# Dakota-3 E&P Company, LLC

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

## Tanks

Uncontrolled NOx:

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

0.00 lb/hr x x 0.00 TPY



### NOx Created by Combustion (Actual)

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

0.50 lb/hr x x 2.18 TPY



### Uncontrolled PM:

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

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



### PM Created by Combustion (Actual)

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

0.02 lb/hr x 8760 hr/yr x 0.10 TPY 1 MMBtu/1,000,000 Btu

8760 hr/yr 1 ton/2000 lb =

=

1 ton/2000 lb = 1 ton/2000 lb = 1 ton/2000 lb 1 MMBtu/1,000,000 Btu

8760 hr/yr

# Dakota-3 E&P Company, LLC

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

## Tanks

Uncontrolled CO:

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

0.00 lb/hr x x 0.00 TPY



### CO Created by Combustion (Actual)

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

2.71 lb/hr x x 11.87 TPY

a NOx, SO2, and CO emission factors are from AP-42 Table 13.5-1 (Emission Factors for Flare Operations). = 1 MMBtu/1,000,000 Btu

8760 hr/yr 1 ton/2000 lb 1 MMBtu/1,000,000 Btu

8760 hr/yr 1 ton/2000 lb =

# Dakota-3 E&P Company, LLC

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

## Tanks

Uncombusted CO2:

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

lb/hr x 8760 hr/yr x = TPY



### CO2 Created by Combustion (Actual)

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

376.08 lb/hr x 8760 hr/yr x = 1647.24 TPY 1 ton/2000 lb x 1/379 scf/lb-mole

1 ton/2000 lb 0.97

4.23

376.08 

## REGULATED GREENHOUSE GAS EMISSIONS b

0.97

# Dakota-3 E&P Company, LLC

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

## Tanks

Uncontrolled CH4:

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

lb/hr x 8760 hr/yr x = TPY



### Controlled CH4: (Actual)

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

lb/hr x 8760 hr/yr x = TPY x 0.15

0.15 0.64 1/379 scf/lb-mole

1 ton/2000 lb x 7.27

7.27 31.86 1/379 scf/lb-mole

1 ton/2000 lb

# Dakota-3 E&P Company, LLC

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

## Tanks

Uncontrolled N2O:

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

lb/hr x 8760 hr/yr x = TPY



### N2O Created by Combustion:

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

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

b CO2 and N2O emission factors are from AP-42 Table 1.4-2 (Emission Factors for Natural Gas Combustion). 0.00 0.00

0.01

1 ton/2000 lb

x 0.00 1/379 scf/lb-mole

1 ton/2000 lbscf/hr (Takes into account the 10% of the total produced gas volume that is not being sold.) Btu/scf

lb/lb-mole

HAP wt fraction Benzene wt fraction E-Benzene wt fraction

Toluene wt fraction n-Hexane wt fraction

Xylene wt fraction 2,2,4-Trimethylpentane wt fraction

CO2 wt fraction

CH4 wt fraction

hours/yr

DRE 

# Dakota-3 E&P Company, LLC

8760 Hours of Flaring for PTE:

Control Effiiciency Maggie Old Dog 19-18H Pad Associated Wells: Maggie Old Dog 19-18H Well #1, Well #2, Well #3, Well #4, Well #5, Well #6, Well #7 

## Casing Head Gas

Flare Gas Volume 5,571

Lower Heating Value 1700.386571

Avg. Molecular Weight 29.65

VOC wt fraction 45.94%

1.28% 0.15% 0.01% 0.18% 0.84% 0.10%

0.00%

0.86%

25.75%

98%

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

Controlled VOCs (PTE):
wt% Control % VOC: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 45.94% x 98% = lb/hr

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



### Controlled VOCs (Allowable):
wt% Control % VOC: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 45.94% x 98% = lb/hr

4.00 lb/hr x 8760 hr/yr x 1 ton/2000 lb = TPY 17.54

4.00

17.54 x 

## CRITERIA POLLUTANT EMISSIONS a

x 4.00

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

Controlled HAPs (PTE):

Using E&P Tanks Run: wt% Control % TPY Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.15% x 98% = 0.01 lb/hr 0.06 E-Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00

Toluene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.18% x 98% = 0.02 lb/hr 0.07 n-Hexane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.84% x 98% = 0.07 lb/hr 0.32

Xylene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.10% x 98% = 0.01 lb/hr 0.04 2,2,4-Trimethylpentane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.00% x 98% = 0.00 lb/hr 0.00 Formaldehyde 5,571 scf/hr 7.50E-02 lb/MMscf = 0.00 lb/hr 0.00

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



### Controlled HAPs (Allowable):

Using E&P Tanks Run: wt% Control % TPY Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.15% x 98% = 0.01 lb/hr 0.06 E-Benzene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.01% x 98% = 0.00 lb/hr 0.00

Toluene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.18% x 98% = 0.02 lb/hr 0.07 n-Hexane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.84% x 98% = 0.07 lb/hr 0.32

Xylene 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.10% x 98% = 0.01 lb/hr 0.04 2,2,4-Trimethylpentane 5,571 scf/hr x x 1/379 scf/lb-mole x 29.64686 lb/lb-mol x 0.00% x 98% = 0.00 lb/hr 0.00 Formaldehyde 5,571 scf/hr x 7.50E-02 lb/MMscf x 1000000 scf/MMscf = 0.00 lb/hr 0.00

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

=

=

= 0.49 =

= =

=

= =

=

=

=

=

0.49

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

Uncontrolled NOx (PTE):

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

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



### NOx Created by Combustion (Actual):

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

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



### Controlled H2S (PTE):
wt% Control % H 2 S: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

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



### Controlled H2S (Actual):
wt% Control % H 2 S: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

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

0.00 = 1 Mmbtu/1,000,000 Btu

1 ton/2000 lb =

x 0.00

0.00 1 ton/2000 lb 1 Mmbtu/1,000,000 Btu

0.00

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

SO2 Created by Combustion (PTE):
wt% Control % SO 2 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

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



### SO2 Created by Combustion (Actual):
wt% Control % SO 2 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.00% x 98% = lb/hr

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



### CO Created by Combustion (PTE):

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

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



### CO Created by Combustion (Actual):

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

3.50 lb/hr x 8760 hr/yr x 15.35 TPY 0.00

0.00

0.00

= 0.00

= 1 ton/2000 lb x

1 Mmbtu/1,000,000 Btu

1 ton/2000 lb x

1 Mmbtu/1,000,000 Btu

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

PM Created by Combustion (PTE):

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

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



### PM Created by Combustion (Actual):

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

0.04 lb/hr x 8760 hr/yr x 0.19 TPY = lb/1,000,000 scf

(Emission Factors for Flare Operations and Natural Gas Combustion). lb/1,000,000 scf

1 ton/2000 lb = 1 ton/2000 lb

a NOx, SO2, PM, & CO emission factors are from AP-42 Table 13.5-1 and Table 1.4-2

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

CO2 (PTE):

CO2 Entrained in the Produced Gas:
Control % CO2: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.86% x 98% = lb/hr

3.76 lb/hr x 8760 hr/yr x 1 ton/2000 lb = 16.46 TPY CO2 Created by Combustion:

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

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

2944.43 TPY 

## REGULATED GREENHOUSE GAS EMISSIONS b

1 ton/2000 lb = x 3.76

lb/1,000,000 scf

Total CO2 Emitted (PTE):

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

CO2 (Actual):

CO2 Entrained in the Produced Gas: wt% Control % CO2: 5,571 scf/hr x 1/379 scf/lb-mole x 29.64686 lb/lb-mole 0.86% x 98% = lb/hr

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

### CO2 Created by Combustion: `

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

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

2944.43 TPY



### Controlled CH4 (PTE):

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

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



### Controlled CH4 (Actual):

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

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

9.83 Total CO2 Emitted (Allowable): 1 ton/2000 lb = lb/1,000,000 scf x

2.24

9.83 x 3.76

# Dakota-3 E&P Company, LLC

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

## Casing Head Gas

N2O Created by Combustion (PTE):

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

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



### N2O Created by Combustion (Actual):

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

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

(Emission Factors for Natural Gas Combustion). 1 ton/2000 lb =

lb/1,000,000 scf lb/1,000,000 scf

b CO2 and N2O emission factors are from AP-42 Table 1.4-2 1 ton/2000 lb =5,250,000 Btu/hr This burner rating reflects the combined size of all of the proposed heater treater burners at the facility.

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

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

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

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

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

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

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

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

# Dakota-3 E&P Company, LLC

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


# Heater Treater Burner a

Burner Rating

# Dakota-3 E&P Company, LLC

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


# Heater Treater Burner a

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

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

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

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

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

6.18E+02 lb/hr x 8,760 hr/yr x 1 ton / 2000 lb = 2,705.294 TPY

# Dakota-3 E&P Company, LLC

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


# Heater Treater Burner a

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

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

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

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

NOx TPY

CO TPY

SO2 TPY

PM TPY

VOC TPY

HAP TPY

CO2 TPY

CH4 TPY

N2O TPY 2705.29

0.15

0.03 1.89

0.12

0.04 0.01

0.17 a NOx, CO, CO2, & VOC Emission Factors are from AP-42 Table 1.4-1 and 1.4-2 (Emission Factors for Nitrogen Oxides (N2O) and Methane come from Table C-1 of Subpart W).

2.25

### Saturation Vapor Molecular Temp + Load Loss Factor (S) Pressure (P) Weight (MW) 460 lb/1000 gal 12.46 x 0.60 x 2.30 x 40.93 / 510.00 = 1.38

LL Truck Load Load Time lb/1,000 gal Rate bbl/hr hrs gal/bbl 1.38 x 180.00 / 1.00 x 42.00 = 10.43

LL Annual Emissions lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 15.03

VOC Emissions Uncontrolled Control % TPY 15.03 100% 0.00 0.00 

# Dakota-3 E&P Company, LLC

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

# Truck Loadout Emission Calculation

Total Gas Emissions lb/hr

Uncontrolled C3+ VOC tpy

### LL Annual Emissions lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 0.15

HAPs Emissions Uncontrolled Control % TPY 0.15 100% 0.00 0.00

LL Annual Emissions lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 0.06

CO2 Emissions Uncontrolled Control % TPY 0.06 100% 0.00 0.00

LL Annual Emissions lb/1,000 gal bbl/yr gal/bbl lb/ton TPY 1.38 x 702149.39 x 42.00 / 2000.00 = 20.35 0.44

CH4 Emissions Uncontrolled Control % TPY 0.44 100% 0.00 0.00 Uncontrolled HAPs tpy

Uncontrolled

CO2 tpy

Uncontrolled

CH4 tpyCombined Diesel Engines Hours of Operation 8760 Maximum HP Rating 1925 NOx g/hp-hr 1.49E+00 CO g/hp-hr 2.61E+00 SO2 g/hp-hr 4.52E-06 PM g/hp-hr 4.85E-06 VOC g/hp-hr 1.42E-01 HAP g/bh-hr 1.02E-06 CO2 g/bh-hr 2.54E-03 CH4 g/bh-hr 2.10E-02 N2O g/hp-hr 4.20E-03

Recycle Pump H ours of Operation 8760 Maximum HP Rating 56 NOx g/hp-hr 4.99E+00 CO g/hp-hr 3.16E+00 SO2 g/hp-hr 2.68E-01 PM g/hp-hr 3.27E-01 VOC g/hp-hr 9.80E+00 HAP g/hp-hr 2.20E-01 CO2 g/bh-hr 4.90E+02 CH4 g/hp-hr 2.10E-02 N2O g/hp-hr 4.20E-03 Description Engine is assumed to operate 8,760 hours per year. Manufacturer's maximum hp rating.
AP-42 Table 3.3-1
AP-42 Table 3.3-1

AP-42 Table 3.3-1 AP-42 Table 3.3-1

AP-42 Table 3.3-1 40 CFR 98 Subpart C, Table C-2 40 CFR 98 Subpart C, Table C-2 AP-42 Table 3.3-1

AP-42 Table 3.3-1 AP-42 Table 3.3-1

AP-42 Table 3.3-1 Manufacturer Guarantee (40 CFR 63 Subpart IIII requirements), see Attachment F AP-42 Table 3.3-1

AP-42 Table 3.3-1 40 CFR 98 Subpart C, Table C-2 40 CFR 98 Subpart C, Table C-2 

# Dakota-3 E&P Company, LLC

RICE Input Data

Description Engine is assumed to operate 8,760 hours per year. Manufacturer's maximum hp rating. Manufacturer Guarantee (40 CFR 63 Subpart IIII requirements), see Attachment F Manufacturer Guarantee (40 CFR 63 Subpart IIII requirements), see Attachment FENGINE #1

1925 MAX HP 0% N Ox DRE 0% CO DRE 0% VOC DRE 0% SO2 DRE 0% HAP DRE 0% PM DRE ##### #### ##### #### ### 100.00%

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

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

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

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

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

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

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

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

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

# Dakota-3 E&P Company, LLC

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

## Reciprocating Engine Emissions

x

x x

x

x x

x x

x

# Dakota-3 E&P Company, LLC

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

## Reciprocating Engine Emissions

56 MAX HP 0% CO DRE 0% VOC DRE 0% SO2 DRE 0% HAP DRE 0% PM DRE ##### #### ##### #### ### 100.00%

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

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

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

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

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

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

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

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

N2O: 4.20E-03 g/HP-HR 56 HP x 1 lb / 453.6 grams = 5.19E-04 lb/hr x 8760 hr/yr x 1 ton / 2000lb = 2.27E-03 N2O TPY ENGINE #2

x x x

x NOx DRE

x

x

x x

x

# Dakota-3 E&P Company, LLC

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

## Reciprocating Engine Emissions

3.04E+01

5.03E+01

1.45E-01

1.77E-01
7.93E+00

1.19E-01

2.65E+02

4.02E-01

8.03E-02 SO2 TPY

CO2 TPY

CH4 TPY

N2O TPY TOTALS NOx TPY

CO TPY

VOC TPY PM TPY

HAP TPYDakota-3 E&P Company, LLC. NSR Synthetic Minor Application WEP211324 

# ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS

• E&P Tanks Emission Summary

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

****************************************************************************************** * Project Setup Information *
****************************************************************************************** Project File : Y:\Projects\Williams Exploration & Production WEP\WEP211324 Ft. Berthold IR Well Work\E&P Tanks\Mandaree Field 1000 BOPD.ept Flowsheet Selection : Oil Tank with Separator Calculation Method : RVP Distillation Control Efficiency : 100.0% Known Separator Stream : Low Pressure Oil Entering Air Composition : No
Filed Name : Mandaree Well Name : Cross 2-13H and Patricia Charging 4-15H Averages Permit Number : Dakota-3 E&P Company, LLC Date : 9/24/2010

****************************************************************************************** * Data Input *
****************************************************************************************** Separator Pressure : 51.00[psig] Separator Temperature : 82.50[F] Ambient Pressure : 14.70[psia] Ambient Temperature : 70.00[F] C10+ SG : 0.8000 C10+ MW : 235.14
-- Low Pressure Oil ---------------------------------------------------------------------- No. Component wt % 1 H2S 0.0014 2 O2 0.0000 3 CO2 0.0042 4 N2 0.0015 5 C1 0.0320 6 C2 0.3654 7 C3 1.2089 8 i-C4 0.3443 9 n-C4 1.5191 10 i-C5 0.6508 11 n-C5 1.2185 12 C6 1.3933 13 C7 6.7524 14 C8 15.9338 15 C9 14.3170 16 C10+ 53.7971 17 Benzene 0.0479 18 Toluene 0.0997 19 E-Benzene 0.0600 20 Xylenes 0.3998 21 n-C6 1.4864 22 224Trimethylp 0.3663
-- Sales Oil ----------------------------------------------------------------------------- Production Rate : 1000[bbl/day] Days of Annual Operation : 365 [days/year] API Gravity : 41.85 Reid Vapor Pressure : 5.90[psia]

****************************************************************************************** * Calculation Results *
****************************************************************************************** -- Emission Summary ---------------------------------------------------------------------- Item Uncontrolled Uncontrolled [ton/yr] [lb/hr] Page 1---------------------------------------------------------------- E&P TANK
Total HAPs 8.550 1.952 Total HC 812.744 185.558 VOCs, C2+ 796.480 181.845 VOCs, C3+ 612.595 139.862 Page 1Mandaree Field 1000 BOPD wt% Uncontrolled Recovery Info. Vapor 40.2300 [MSCFD] HC Vapor 40.0300 [MSCFD] GOR 40.23 [SCF/bbl] -- Emission Composition ------------------------------------------------------------------ No Component Uncontrolled Uncontrolled [ton/yr] [lb/hr] 1 H2S 0.689 0.157 2 O2 0.000 0.000 3 CO2 2.160 0.493 4 N2 0.786 0.179 5 C1 16.264 3.713 6 C2 183.886 41.983 7 C3 375.375 85.702 8 i-C4 37.149 8.482 9 n-C4 112.787 25.750 10 i-C5 17.863 4.078 11 n-C5 24.862 5.676 12 C6 8.648 1.974 13 C7 13.803 3.151 14 C8 10.281 2.347 15 C9 3.270 0.747 16 C10+ 0.004 0.001 17 Benzene 0.234 0.053 18 Toluene 0.136 0.031 19 E-Benzene 0.027 0.006 20 Xylenes 0.156 0.036 21 n-C6 7.394 1.688 22 224Trimethylp 0.604 0.138 Total 816.378 186.388

-- Stream Data --------------------------------------------------------------------------- No. Component MW LP Oil Flash Oil Sale Oil Flash Gas W&S Gas Total Emissions wt % wt % wt % wt % wt % wt % 1 H2S 34.80 0.0014 0.0010 0.0000 0.0873 0.0856 0.0861 2 O2 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 3 CO2 44.01 0.0042 0.0020 0.0000 0.4818 0.1765 0.2642 4 N2 28.01 0.0015 0.0001 0.0000 0.3044 0.0123 0.0962 5 C1 16.04 0.0320 0.0079 0.0000 5.2226 0.6866 1.9891 6 C2 30.07 0.3654 0.2356 0.0039 28.3624 20.1288 22.4930 7 C3 44.10 1.2089 1.0468 0.4786 36.1613 49.8497 45.9192 8 i-C4 58.12 0.3443 0.3257 0.2757 4.3503 4.6218 4.5438 9 n-C4 58.12 1.5191 1.4623 1.3185 13.7647 13.8076 13.7953 10 i-C5 72.15 0.6508 0.6432 0.6257 2.2771 2.1480 2.1850 11 n-C5 72.15 1.2185 1.2094 1.1888 3.1795 2.9854 3.0410 12 C6 86.16 1.3933 1.3945 1.3984 1.1369 1.0640 1.0850 13 C7 100.20 6.7524 6.7753 6.8342 1.8207 1.7133 1.7442 14 C8 114.23 15.9338 16.0015 16.1730 1.3430 1.2744 1.2941 15 C9 128.28 14.3170 14.3815 14.5440 0.4133 0.4189 0.4174 16 C10+ 235.14 53.7971 54.0465 54.6758 0.0006 0.0005 0.0006 17 Benzene 78.11 0.0479 0.0480 0.0483 0.0298 0.0281 0.0285 18 Toluene 92.13 0.0997 0.1001 0.1011 0.0174 0.0165 0.0166 19 E-Benzene 106.17 0.0600 0.0603 0.0610 0.0035 0.0032 0.0033 20 Xylenes 106.17 0.3998 0.4016 0.4059 0.0196 0.0187 0.0191 21 n-C6 86.18 1.4864 1.4889 1.4959 0.9466 0.8874 0.9045 22 224Trimethylp 114.24 0.3663 0.3677 0.3711 0.0772 0.0726 0.0739

MW 143.08 144.90 148.98 39.02 43.55 42.14 Stream Mole Ratio 1.0000 0.9829 0.9448 0.0171 0.0381 0.0552 Heating Value [BTU/SCF] 2225.52 2481.29 2401.97 Gas Gravity [Gas/Air] 1.35 1.50 1.45 Bubble Pt. @ 100F [psia] 32.28 20.39 7.37 Page 2---------------------------------------------------------------- E&P TANK RVP @ 100F [psia] 15.35 12.04 6.01 Spec. Gravity @ 100F 0.677 0.678 0.680

Page 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 Mandaree Field Dakota-3 Wells Separator: 51 psig, 83 degF Flash Valve: 13.7 psia, 50 degF Sales Oil: API Gravity 41.9, Reid Vapor Pressure 5.90 psia, 365 days/year
Outputs: Oil Production Rates (bbl/day) (P) 0 50 100 300 1000 Emission (tons/yr) Total HC 0 40.6372 81.2744 243.8232 812.744 VOCs, C3+ 0 30.62975 61.2595 183.7785 612.595 Total HAPs 0 0.4275 0.855 2.565 8.55
VOC (C3+) Emission Factor: 0.6126 tpy/BOPD HAP Emission Factor: 0.00855 tpy/BOPD Oil Storage Tank Flashing Emissions Calculation Methodology E&P Tanks Linear Relation between Production (bbls/day) and Emissions (tons/yr)

y = 0.00855x R 2 = 1.00000 y = 0.6126x R 2 = 1

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 2 Date Sampled

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

Ͳ 15

Ͳ 2010 Date Tested............. 7

Ͳ 23

Ͳ 2010

S l Id tifi ti CROSS 2 13 H CRUDE OIL 

### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

Samp l e I d enti f ication

.................... C R OSS 2-13 H C RUDE O IL



### Sample Location .......... MONTANA. Sample Pressure ......... 22 PSIG Sample Temperature.... 95 F Type Sample ............... SPOT County...................... DUNN Test method ................ 

### GPA

Ͳ 2286 Sampling Method........ YZ PISTON

Components Mole % Weight % Liq. Vol. % Hydrogen Sulfide

.......... 0.003 0.001 0.001 

### Oxygen

...................... 0.000 0.000 0.000 

### Carbon Dioxide

............ 0.013 0.004 0.004 

### Nitrogen

..................... 0.007 0.001 0.001 

### Methane 0 180 0 021 0 050



### ..................... . . . 

### Ethane

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

### Propane

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

### iso

Ͳ Butane

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



### n

Ͳ Butane

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

### iso

Ͳ Pentane

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



### n

Ͳ Pentane

................... 2.569 1.316 1.540 

### H 2 510 1 536 1 707 

### exanes

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

### Heptanes

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

### Octanes

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

### Nonanes

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

### Decanes+

................... 31.435 51.099 47.376 

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

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

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

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



### n

Ͳ Hexane

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

### 2,2,4

Ͳ Trimethylpentane... 0.542 0.440 0.466 

### TOTALS

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



### Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.486 0.910 1.011 3-Methylpentane 1 024 0 627 0 696 3

- Methylpentane

. . . n-Hexane 2.798 1.712 1.903 2,2,4-Trimethylpentane 0.542 0.440 0.466
Benzene 0.093 0.052 0.043
Toluene 0.166 0.109 0.092 Ethylbenzene 0.104 0.078 0.066 m-Xylene 0.066 0.050 0.042 p-Xylene 0.436 0.329 0.280 o-Xylene 0.116 0.087 0.074

API GRAVITY AT 60/60 F, calculated........................................................................ 60.3 SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 0.7378 RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.7958 AVERAGE MOLECULAR WEIGHT .......................................................................... 140.803 AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 228.881 TRUE VAPOR PRESSURE AT 100 F PSIA calculated 33 400 TRUE VAPOR PRESSURE AT 100 F
, PSIA
, calculated

................................................ . AVERAGE BOILING POINT, F, ................................................................................ 299.063 CUBIC FEET OF GAS / GALLON OF LIQUID, as Ideal Gas .......................................... 19.106 BTU / GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 122456.887 LBS / GALLON OF LIQUID, calculated ...................................................................... 6.152

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

OF PHYSICAL CONSTANTS FOR HYDROCARBONS AND OTHER COMPOUNDS OF INTEREST

TO THE NATURAL GAS INDUSTRY.

### EXTENDED HYDROCARBON LIQUID STUDIES



## CERTIFICATE OF ANALYSIS

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

L bN b CR 10330 St d N b a umer............. CR-10330 Study Number............ CR-2B Date Sampled............. 7-15-2010 Date Tested.............. 7-22-2010

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

Sample Location......... MONTANA. Sample Pressure.......... N/A Sample Temperature.... N/A
Flowrate................... N/A County..................... DUNN

Test Method.............. VARIOUS Sample Container........ 1-QUART BOTTLE

TEST PERFORMED RESULTS

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

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

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

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

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

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

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

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

NOTATION : ALL TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY OUTLINED BY THE AMERICAN SOCIETY FOR TESTING AND MATERIALS (ASTM).

### 5HSRUW5HSRUW(GLWRU

Chromatogram Cross 2-13H C:\GCsolution\DRO\DRO Data\08-2010\08-01-2010\Cross 2-13H.gcd - Channel 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 / 1.306 / 1.405 / 1.552 / 1.668 / 1.729 / 1.901 / 1.979 / 2.039 / 2.109 / 2.280 / 2.417 / 2.565 / 2.667 / 2.854 / 2.949 / 3.034 / 3.092 / 3.213 / 3.342 / 3.420 / 3.539 / 3.632 / 3.773 / 3.862 / 3.965 / 4.069 / 4.148 / 4.335 / 4.448 / 4.508 / 4.583 / 4.692 / 4.751 / 4.901 / 5.021 / 5.164 / 5.365 / 5.508 / 5.608 / Decane (C10) 5.816 / 5.947 / 6.069 / 6.188 / 6.286 / 6.393 / 6.509 / 6.569 / 6.657 / 6.714 / 6.777 / 6.896 / 7.083 /

7.220 / 7.323 / 7.381 / 7.455 / 7.559 / 7.632 / 7.703 / 7.769 / 7.836 / 7.907 /

7.967 / 8.056 / 8.184 / 8.268 / 8.329 / 8.452 / 8.540 / 8.633 /

8.744 / 8.808 /

8.998 / 9.128 /

9.270 / 9.380 / 9.467 / 9.526 / 9.596 / 9.724 / 9.862 / 9.939 / 10.055 / 10.150 / 10.257 / 10.332 / 10.427 / 10.487 / 10.568 / 10.638 / 10.766 /

10.828 / 10.911 / 11.051 / 11.216 / 11.469 /

11.613 / 11.706 / 11.785 / 12.031 /

12.128 / 12.182 / 12.302 / 12.409 / 12.463 / 12.536 / 12.607 / 12.700 / 12.822 / 13.004 / 13.088 / 13.203 / 13.305 / 13.372 / 13.447 / 13.582 / 13.674 / 13.803 / 13.929 / 14.089 / 14.146 / 14.316 / 14.427 /

14.515 / 14.592 / 14.691 / 14.773 / 14.896 / 15.041 / 15.129 / 15.249 / 15.300 /

15.369 / 15.430 / 15.566 / 15.620 / 15.691 / 15.787 / 15.947 / o-terphenyl 16.113 / 16.187 / 16.339 / 16.456 / 16.570 / 16.661 / 16.813 / 16.894 / 16.979 / 17.143 /

17.306 / 17.449 / 17.519 / 17.642 / 17.787 / 17.954 / 18.052 / 18.153 / 18.222 / 18.292 / 18.434 / 18.549 / 18.723 / 18.887 / 18.991 / 19.197 / 19.331 / 19.474 / 19.663 / 19.724 / 19.785 / 19.850 / 19.927 / 19.995 / 20.077 / 20.182 / 20.222 / 20.345 / 20.443 / 20.634 / 20.789 / 20.871 / 20.945 / 21.059 / 21.134 / 21.205 / 21.310 / 21.542 / 21.695 / 21.795 / 21.855 / 21.905 / 21.966 / 22.073 / 22.181 / 22.367 / 22.425 /

22.599 / Octacosane (C28) 22.737 / 22.808 / 22.879 / 23.003 / 23.058 / 23.117 /

23.217 / 23.351 / 23.418 / 23.678 /

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

### Company

.................... ZENERGY 

### Lab Number

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

Ͳ 10330 Study Number.......... CR

Ͳ 3 Date Sampled

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

Ͳ 15

Ͳ 2010 Date Tested............. 7

Ͳ 23

Ͳ 2010

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

### EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY

Samp l e I d enti f ication

.................... PATRI C IA C HAR G IN G 4-15 H C RUDE O IL



### Sample Location .......... MONTANA. Sample Pressure ......... 80 PSIG Sample Temperature.... 70 F Type Sample ............... SPOT County...................... DUNN Test method ................ 

### GPA

Ͳ 2286 Sampling Method........ YZ PISTON

Components Mole % Weight % Liq. Vol. % Hydrogen Sulfide

.......... 0.008 0.002 0.002 

### Oxygen

...................... 0.000 0.000 0.000 

### Carbon Dioxide

............ 0.014 0.004 0.004 

### Nitrogen

..................... 0.008 0.001 0.001 

### Methane 0 398 0 043 0 107



### ..................... . . . 

### Ethane

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

### Propane

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

### iso

Ͳ Butane

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



### n

Ͳ Butane

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

### iso

Ͳ Pentane

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



### n

Ͳ Pentane

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

### H 2 180 1 257 1 415 

### exanes

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

### Heptanes

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

### Octanes

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

### Nonanes

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

### Decanes+

................... 34.917 56.412 52.378 

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

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

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

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



### n

Ͳ Hexane

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

### 2,2,4

Ͳ Trimethylpentane... 0.387 0.296 0.317 

### TOTALS

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



### Components Mole % Weight % Liq. Vol. % 2-Methylpentane 1.272 0.734 0.826 3-Methylpentane 0 908 0 524 0 590 3

- Methylpentane

. . . n-Hexane 2.204 1.271 1.431 2,2,4-Trimethylpentane 0.387 0.296 0.317
Benzene 0.085 0.044 0.038
Toluene 0.148 0.091 0.078 Ethylbenzene 0.060 0.043 0.037 m-Xylene 0.058 0.041 0.036 p-Xylene 0.298 0.212 0.183 o-Xylene 0.117 0.083 0.072

API GRAVITY AT 60/60 F, calculated........................................................................ 57.8 SPECIFIC GRAVITY AT 60/60 F, calculated.............................................................. 0.7475 RELATIVE SPECIFIC GRAVITY OF DECANES+ (C10+) FRACTION ............................... 0.8050 AVERAGE MOLECULAR WEIGHT .......................................................................... 149.417 AVERAGE MOLECULAR WEIGHT OF DECANES+ (C10+) FRACTION .......................... 241.399 TRUE VAPOR PRESSURE AT 100 F PSIA calculated 46 319 TRUE VAPOR PRESSURE AT 100 F
, PSIA
, calculated

................................................ . AVERAGE BOILING POINT, F, ................................................................................ 314.836 CUBIC FEET OF GAS / GALLON OF LIQUID, as Ideal Gas .......................................... 18.857 BTU / GALLON OF LIQUID AT 14.73 PSIA, calculated ................................................. 122700.693 LBS / GALLON OF LIQUID, calculated ...................................................................... 6.232

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

OF PHYSICAL CONSTANTS FOR HYDROCARBONS AND OTHER COMPOUNDS OF INTEREST

TO THE NATURAL GAS INDUSTRY.

### EXTENDED HYDROCARBON LIQUID STUDIES



## CERTIFICATE OF ANALYSIS

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

L bN b CR 10330 St d N b a umer............. CR-10330 Study Number............ CR-3B Date Sampled............. 7-15-2010 Date Tested.............. 7-22-2010

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

Sample Location......... MONTANA. Sample Pressure.......... N/A Sample Temperature.... N/A
Flowrate................... N/A County..................... DUNN

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.............. 6.6 PSIG

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

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

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

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

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

NOTATION : ALL TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDANCE TO METHODOLOGY OUTLINED BY THE AMERICAN SOCIETY FOR TESTING AND MATERIALS (ASTM).

### 5HSRUW5HSRUW(GLWRU

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

1.054 / 1.137 / 1.407 / 1.593 / 1.670 / 1.730 / 1.902 / 2.040 / 2.109 / 2.280 / 2.363 /

2.418 / 2.566 / 2.667 / 2.855 / 2.950 / 3.035 / 3.136 /

3.214 / 3.343 / 3.421 / 3.540 / 3.635 / 3.773 / 3.863 / 3.967 / 4.070 / 4.149 / 4.335 / 4.509 / 4.584 / 4.694 / 4.750 / 4.901 / 5.022 / 5.166 / 5.366 / 5.510 / 5.610 / Decane (C10) 5.818 / 5.949 / 6.070 / 6.190 / 6.288 / 6.397 / 6.512 / 6.564 / 6.660 / 6.714 / 6.780 / 6.901 / 7.016 / 7.084 / 7.156 / 7.221 /

7.326 / 7.384 / 7.457 / 7.561 / 7.634 / 7.747 / 7.836 / 7.908 /

7.969 / 8.059 / 8.184 / 8.270 / 8.331 / 8.453 / 8.542 / 8.634 / 8.745 / 8.812 / 9.000 / 9.129 /

9.271 / 9.381 / 9.469 / 9.529 / 9.597 / 9.725 / 9.863 / 9.942 / 10.057 / 10.149 / 10.260 / 10.334 / 10.429 /

10.488 / 10.570 / 10.640 / 10.768 /

10.830 / 10.913 /

11.059 / 11.220 / 11.472 / 11.615 / 11.787 / 12.031 / 12.130 / 12.184 / 12.318 / 12.414 / 12.470 / 12.541 / 12.606 / 12.706 / 12.826 / 13.005 / 13.088 / 13.306 / 13.376 / 13.450 / 13.583 / 13.673 / 13.728 / 13.934 / 14.091 / 14.148 / 14.319 / 14.445 /

14.516 / 14.595 / 14.692 / 14.779 / 14.896 / 15.042 / 15.130 / 15.246 /

15.373 / 15.431 / 15.568 / 15.621 / 15.658 / 15.775 /

15.883 / 15.950 / o-terphenyl 16.056 / 16.118 / 16.191 / 16.341 / 16.460 / 16.573 / 16.667 / 16.814 / 16.894 / 16.987 / 17.144 / 17.313 / 17.452 / 17.528 / 17.644 / 17.796 / 17.963 / 18.087 / 18.144 / 18.226 / 18.292 / 18.436 / 18.558 / 18.723 / 18.924 / 18.986 / 19.083 / 19.198 / 19.272 / 19.329 / 19.473 / 19.627 / 19.786 / 19.849 / 19.928 / 20.077 / 20.180 / 20.244 / 20.372 / 20.431 / 20.488 / 20.634 / 20.798 / 20.870 / 20.952 / 21.027 / 21.131 / 21.218 / 21.313 / 21.422 / 21.538 / 21.594 / 21.705 / 21.795 / 21.845 / 21.966 / 22.068 / 22.188 / 22.368 / 22.426 / 22.604 / Octacosane (C28) 22.717 / 22.799 / 22.997 / 23.054 /

23.217 / 23.347 / 23.408 / 23.605 / 23.663 /

23.817 / 24.040 / 24.163 / 24.292 / 24.402 / 24.498 / 24.572 / 24.634 / 24.695 / 24.758 / 24.836 / 24.977 / 25.088 / 25.178 / 25.438 / 25.504 / 25.571 / 25.721 / 25.797 / 26.044 / 26.117 / 26.208 / 26.366 / 26.438 / 26.526 / 26.626 / 26.733 / 26.830 / 26.947 / 27.166 / 27.448 / 27.552 / 27.669 / 27.776 / 27.974 / 28.293 / 28.432 / 28.616 / 28.720 / 28.944 / 29.074 / 29.336 / 29.688 / 29 920 /Dakota-3 E&P Company, LLC. NSR Synthetic Minor Application WEP211324 

# ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS

## 	

	



 	
  
      
    
   
    
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	Dakota-3 E&P Company, LLC. NSR Synthetic Minor Application WEP211324 

# ATTACHMENT F: ENGINE MANUFACTURER’S SPECS

# This section of the document has been redacted because it contains copyrighted information. The redacted information

can be viewed from the hard copy of the docket, which is available at the EPA Region 8 Office upon request.

# RENTAL**C~TERPILLAR@**

• 

# XQ230 

# SOUND ATTENUATED
DUAL VOLTAGE 50/60 Hz

Arrangement shown with optional trailer



### FEATURES

EMISSIONS

• EPA Tier 3 and CARS Emissions Certified for

non-road mobile applications at all 60 Hz and 50 Hz ratings
CAT C9 ATAAC DIESEL ENGINE

• Utilizes ACERT® Technology

• Reliable, rugged, durable design

• Field-proven in multiple applications

worldwide

• Four-stroke-cycle diesel engine combines

durability with minimum weight while providing dependability and economy

• 50/60 Hz convertibility
CAT SR4B GENERATOR

• Designed to match performance and output

characteristics of diesel engines

• Permanent magnet excitation

• Segregated AC/DC, low voltage accessory box

provides single point access to accessory connections
ENCLOSURE

• Made with 12-gauge steel

• Single point lifting eye

• Sound attenuated

• Convenient hand holds and steps for safe

operation

• Two coat polyester powder-coated finish

LEHE5329-03 ENVIRONMENTALLY FRIENDLY DESIGN

• Sound attenuated for low noise operation

• OSHA compliant safe design

• 110% spill containment for coolant and oil

• 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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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 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 MANDAREE AREA **SEVEN WELL PAD FACILITY PLOT PLAN Dakota-3 E&P Company, LLC**  **FBIR, North Dakota**

**NOT TO SCALE**

12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl Prod. H2O **Recycle Pump**  **Vent lines Chemicals** 

**(7)Wellheads**

**Tank Vent line**

Utility F lare **LACT Gas to sales**  **Gas Meter**

12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl Prod. H2O 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl Prod. H2O 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl Prod. H2O 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl Prod. H2O 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl Prod. H2O

12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil Enclosed Combustor

**Recycle Pump**  **Recycle Pump**  **Recycle Pump**  **Recycle Pump** 

**Recycle Pump** 

**Recycle Pump**  **LACT Unit** 

**LACT Unit** 

**LACT Unit** 

**LACT Unit** 

**LACT Unit**  **LACT Unit**  12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil

12’d x 20’h 400 bbl oil

12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil

12’d x 20’h 400 bbl 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil

12’d x 20’h 400 bbl oil

12’d x 20’h 400 bbl oil 12’d x 20’h 400 bbl oil

12’d x 20’h 400 bbl oil **Valve Valve** 

**Valve**

**Valve**

**Valve Valve** 

**Valve**

**Recycle Line** 6’d x 20’h vertical treater Separator 30” d by 10’ h

6’d x 20’h vertical treater Separator 30” d by 10’ h

6’d x 20’h vertical treater Separator 30” d by 10’ h

6’d x 20’h vertical treater Separator 30” d by 10’ h

6’d x 20’h vertical treater Separator 30” d by 10’ h

6’d x 20’h vertical treater Separator 30” d by 10’ h

6’d x 20’h vertical treater Separator 30” d by 10’ h Gas Meter **(7) Gensets Genset** 

**Oil Pipeline Water**  **Pipeline** 24 bbl Diesel

Gas Meter

Legend

Berms Water Line Crude Line Flowline Buried Recycle Lines Gas Sales Line Tank Vapor Line Flared Gas Line	

 	





 

#  
		Dakota-3 E&P Company, LLC. NSR Synthetic Minor Application WEP211324 

# ATTACHMENT J: DIESEL TANK EPA TANKS 4.09D **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