• 


APPLICATION FOR AN NSR 

PSnffITLE V SYNTHETIC MINOR 

AIR QUALITY PERMIT 

OLSON-FBIR 

PAD OIL & GAS 

\~ff.()DU~TI"FA_........... 

, . i. ,:~~!:,"", ;' ", ." C::>'>'C{~>L' • . , ~1: .~1ft!!$IfIf' 

"("f,,:~~. 

~ ~':'~~;,. ' . 

Prepared by: 

Bison Engineering, Inc. 

1400 11th 

www. 

_ """~ "­ ,~T 

December 29, 2011 

--­ -- ,. 
• 


DAKOTA·3 E&P COMPANY, LtC 

8 subsldinry ofWlJllnms 

1001 17'" Slreel. Suile 1200 

Denver, CO 80202 

303/527·3900 

DEC 2') 2011 

8P-AR 

Decem ber 29, 20 JI 

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

Minor NSR Permitting Coordinator r8airpennitting@epa.gov 

• 

U.S. EPA, Region 8 


1595 Wynkoop Avenue, 8P-AR 


Denver, CO 80202-1129 

Re: Synthetic Minor Source Permit Application for the Olson-FBlR Pad 

Dear Ms. Paser: 

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

Source Permit Application for the Olson-FBIR Pad. This application is being submitted in accordance 

with the requirements of Federal Minor New Source Review Rule. 

Do Hot hesitate to contact me with any questions either by phone at 303-606-4056, or bye-mail at 

JoDeII.Mizoue@Williams.com. 

Sincerely, 

• JoDell Mizoue, P.E 

Staff Environmental Specialist 

Attachment 

cc: 	 File 

Joe Gillies Jr. Envjronmental 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) 

• 

• C. CONTACT INFORMATION 

• 


• 


Company Contact: JoDell Mizoue Title: 

Staff Environmental 

Specialist 

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

Email Address: JoDell.Mizoue@Williams.com 

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

Operator Contact (ifdifferent 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 ofthe following information (see the attached instructions) 

./ 	 FORM SYNMIN - New Source Review Synthetic Minor Limit Request Form, if synthetic minor limits are 

being requested . 

./ 	Narrative description of the proposed production processes. This description should follow the flow of 

the process flow diagram to be submitted with this application . 

./ 	Process flow chart identifying all proposed processing, combustion, handling, storage, and emission control 

equipment. 

./ 	 A list and descriptions of all proposed emission units and air pollution-generating activities . 

./ 	Type and quantity of fuels, including sulfur content of fuels, proposed to be used on a daily, annual and 

maximum hourly basis. 

./ 	Type and quantity of raw materials used or final product produced proposed to be used on a daily, annual and 

maximum hourly basis . 

./ 	Proposed operating schedule, including number of hours per day, number of days per week and number of 

weeks per year . 

./ 	 A list and description of all proposed emission controls, control efficiencies, emission limits, and monitoring 

for each emission unit and air pollution generating activity . 

./ 	Criteria Pollutant Emissions - Estimates of Current Actual Emissions, Current Allowable Emissions, PostChange Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants: 

particulate matter, PMIO, PM2.5, 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 (H2S04), hydrogen sulfide (H2S), total reduced sulfur (TRS) and reduced sulfur compounds, including all 

calculations for the estimates . 

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

total. 

./ 	Modeling - Air Quality Impact Analysis (AQIA) 

./ 	ESA (Endangered Species Act) 

./ 	NHPA (National Historic Preservation Act) 
• 


E. TABLE OF ESTIMATED EMISSIONS 


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

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

EO) - Proposed New Facility 

• 

Pollutant Potential Emissions 

(tpy) 

Proposed Allowable 

Emissions 

(tpy) 

PM - Particulate Matter 

PMIO - Particulate Matter less 

than 10 microns in size 

PM2.5 ­ Particulate Matter less 

than 2.5 microns in size 

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic 

Compound 

Pb - Lead and lead compounds 

Fluorides - Gaseous and 

particulates 

H2S04 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur 

Compounds 

PM 0.61 0.76 

PMu 0.61 0.76 

PM 2.S 0.61 0.76 

SOl 0.16 0.16 

NO. 36.93 40.27 

CO 75.18 93.37 

VOC 1816.12 94.98 

Pb Negligible Negligible 

Fluorides Negligible Negligible 

H2SO4 Negligible Negligible 

H2S Negligible Negligible 

TRS Negligible Negligible 

RSC Negligible Negligible 

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

sources, pursuant to CAA Section 3020): 

(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 ofrefuse per day; 

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

0) Petroleum refineries; 

(k) Lime plants; 

(I) Phosphate rock processing plants; 

(m) Coke oven batteries; 

(n) Sulfur recovery plants; 

(0) Carbon black plants (furnace process); 

(P) Primary lead smelters; 

(q) Fuel conversion plants; 

( 

1

• 

•

I 

(r) Sintering plants; 

(s) Secondary metal production plants; 

(t) Chemical process plants I

(u) Fossil-fuel boilers (or combination thereof) totaling I 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 ofmore that 

I 

250 million British thermal units per hour heat input, 

and 

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

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

112 ofthe Act. 

I 

I 

• 

E(ii) Proposed New Construction at an Existing Facility or Modification of an Existing Facility 

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

• 

• 

• 

• 

Pollutant Current 

Actual 

Emissions 

(tpy) 

Current 

Allowable 

Emissions 

(tpy) 

Post-Change 

Potential 

Emissions 

(tpy) 

Post-Change 

Allowable 

Emissions 

(tpy) 

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

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

PM 2.5 N/A N/A N/A N/A 

SO, N/A N/A N/A N/A 

NO, N/A N/A N/A N/A 

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

VOC N/A N/A N/A N/A 

Pb N/A N/A N/A N/A 

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

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

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

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

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

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

PM - PartIculate Matter 

PM'Q - Particulate Matter less than 10 microns in size 

PM2.

s - Particulate Matter less than 2.5 microns in size 

SOx - Sulfur Oxides 

NOx - Nitrogen Oxides 

CO - Carbon Monoxide 

VOC - Volatile Organic Compound 

Pb - Lead and lead compounds 

NH3 - Ammonia 

Fluorides - Gaseous and particulates 

H2S04 - Sulfuric Acid Mist 

H2S - Hydrogen Sulfide 

TRS - Total Reduced Sulfur 

RSC - Reduced Sulfur Compounds 
• Instructions 

Use of This Form 

• 	 Proposed new construction or modifications should first be evaluated to determine ifthe change is 

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

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

that test, then it may be subject to the requirements 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. J52(d) - Modification means any physical or operational change at a source that would 

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

pollutant or that would cause the emission ofany 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 ofoperation or in the production rate is not considered an operational 


change unless such increase is prohibited under any federally-enforceable permit condition or 


other permit condition that is enforceable as a practical matter. 


(3) A change in ownership at a source is not considered a modification. 

• 	 40 CFR 49. J52(d) - Allowable emissions means "allowable emissions" as defmed in I 

§52.2I(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. r 

i 

• 	 52.2J(b)(J6) - Allowable emissions means the emissions rate ofa stationary source calculated i using the maximum rated capacity ofthe source (unless the source is subject to federally 


enforceable limits which restrict the operating rate, or hours ofoperation, or both) and the most 
 l stringent ofthe following: 

f (i) The applicable standards as set forth in 40 CFR parts 60 and 61; 	 I 

• (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 7 ofl5 

• 

• 

• 

• 

• 

A. General Facility Information 

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

corporations, include divisions or subsidiary name, if any. 

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

contain one or more air pollution emitting units. 

3. Type 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 ofportable 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#Sl). 

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

Classification System (NAICS) has replaced the SIC codes, much ofthe 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 (ht1:j:l:llwww.osha.gov/plslimis/sic manua1.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. 

I la & lIb. Latitude & Longitude: These are GPS (global positioning system) coordinates. This information 


can be provided in decimal format or degree-minute-second format. 


12a 12d. Section-Township-Range: Please provide these coordinates in 114 SectionlSection/TownshiplRange. 

(e.g., SW 1/4, NE %/S36ITI0NIR21E). 

Page 8 of 15 
• B. Current Permit Information 

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

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

permit number must be included with each permit identified. 

C. 	 Contact Information 

Please provide the information requested in full. 

I. Company Contact: List the full name (last, middle initial, first) ofthe 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. CompJiance 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 ofthe 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 (Le., 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 9 of 15 

• 

• 

• 

• 

• 

./ 	 A process flow chart identifying all proposed processing, combustion, handling, storage, and emission 

control equipment (include the unit identification # or code), This flow chart should illustrate the detailed 

narrative description requested above . 

./ 	List and describe all proposed units, emission units and air pollution-generating activities. At a 

minimum, provide the following: 

1. 	 The hourly, daily and annual maximum operating rates for each operating unit, 


production process, and activity. 


2. 	 The hourly, daily and annual maximum firing rates for each fuel and combustion 


equipment. 


3. 	 The capacity for storage units and the hourly, daily and annual maximum throughput 


of material in the storage units. 


4. 	 Material and product handling equipment and the hourly, daily and annual maximum 


throughput of material and product. 


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


of material and product. 


./ 	Type and quantity of fuels, including sulfur content offuels, 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 ofdays per week and number of 

weeks per year. 

./ 	 A list and description of all proposed emission controls, control efficiencies, emission limits, and 

monitoring for each emission unit and air pollution generating activity. 

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

Page 10 ofl5 
• Criteria Pollutant Emissions Estimates 

./ 	Estimates ofCurrent Actual Emissions, Current Allowable Emissions, Post-Change Uncontrolled 

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

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

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

particulate), sulfuric acid mist (H2S04), hydrogen sulfide (H2S), total reduced sulfur (TRS) and 

reduced sulfur compounds, including all calculations for the estimates. 

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 ofthe supporting calculations, assumptions and 

references. Emission estimates must address all emission units and pollutants proposed 

and/or affected by the limitation and be presented in short term (e.g. pounds per hour) 

as well as annual (tons per year) units. 

3. 	 Any emission estimates submitted to the Regional Administrator must be verifiable 

using currently accepted engineering criteria. The following procedures are generaUy 

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/ttnichief/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 

(lbslhr) times actual hours operated (which is the number ofhours in a year) and dividing 

by 2,000 (which is the number ofpounds in a ton). 

• 	 1. For an existing air pollution source (permitted and unpermitted) that operated prior to the 

application submittal, the current actual emissions are the actual rate of emissions for the 

preceding calendar year and must be calculated using the actual operating hours, production 

rates, in-place control equipment, and types ofmaterials processed, stored, or combusted 

during the preceding calendar year. The emission estimates must be based upon actual test data 

or, in the absence of such data, upon procedures acceptable to the Regional Administrator. 

Current Allowable Emissions: Current allowable emissions for a pollutant is expressed in tpy and 

generally is calculated by mUltiplying the allowed hourly emissions rate in pounds per hour (lbslhr) 

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

number ofpounds in a ton). 

I. 	 "Allowed" means the source is restricted by permit conditions that limit its emissions and are 

enforceable as a practical matter (i.e., allowable emissions). The allowable emissions for any 

Page II of 15 

• 

• 

emissions unit are calculated considering any emissions limitations that are enforceable as a 


practical matter on the unit's PTE. 


2. 	 For an existing permitted air pollution source that operated prior to the application submittal, the 

current allowable emissions are the allowable rate of emissions for the preceding calendar year and must 

be calculated using the permitted operating bours, 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 (lbslhr) times 8,760 hours (which is the number ofhours in a year) and • 

dividing by 2,000 (which is the number ofpounds in a ton). 

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

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

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

is the number ofpounds 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 ofallowable 


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 offollowing: 


• 	 For each new emissions unit that is to be added, the emissions increase would be the 


potential to emit ofeach unit. 


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


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


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


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


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

•

calculation. 

• 	 For each unpermitted emissions unit (i.e., a unit without any emissions limitations before 


the change) that is to be changed or replaced, the emissions increase would be the 


allowable emissions ofthe unit after the change or replacement minus the potential to emit 


prior to the change or replacement. However, this may not be a negative value. Ifthe 


allowable emissions ofan emissions unit would be reduced as a result ofthe change or 


replacement, use zero in the calculation. 


•

Page 12 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) ofproposed 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, ifthe AQIA reveals that the new construction could cause or contribute to a NAAQS or 

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

issued. 

• 

To facilitate the protection of the NAAQS and PSD Increment, EPA Region 8 requests that those 

proposed activities that meet the following criteria perform an AQIA: 

1. 	 The proposed activity has air emissions that EPA Region 8 determines have the potential to 

cause adverse air quality effects for which an air quality impact analysis is necessary for an 

accurate assessment ofthe environmental impact ofthe activities proposed. 

2. 	 Modeling ofproposed emissions is usually warranted, even though the proposed activity does 

not meet the modeling requirements, above, if it is reasonable to believe the new activity may 

cause or contribute to a violation of applicable ambient air quality standards or increments in 

circumstances such as: 

(a) A substantial portion ofthe new or modified emissions have poor dispersion characteristics 

(e.g., rain caps, horizontal stacks, fugitive releases, or building downwash) in close 

proximity to ambient air at the site boundary; 

(b) The new or modified emissions are located in complex terrain (e.g., terrain above stack 

height in close proximity to the source); or 

(c) The new or modified emissions are located in areas with existing air quality concerns. 

(d) If you have questions about whether modeling may be necessary based on the 4th criteria 

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

• 	 Gail Tonnesen 

Region 8 Modeling Lead 


Tonnesen.gail@epa.gov 


303-312- 6113 


Page 13 of 15 

• 
• 

What Kind ofAir Quality Modeling Analysis Is Needed? 

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

follows: 

Step I: Qualitative Air Quality Assessment 

Step 2: Screening Modeling Analysis 

Step 3: 	 Preliminary Modeling Analysis (refined modeling) 

Step 4: Full Impact Modeling Analysis (refmed modeling) 

Step 5: PSD Increment and NAAQS Analysis 

Step 6: Additional Impact Analysis 

2. 	 Step I: Qualitative Air Quality Assessment 

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

source would have on that air quality. Some suggested factors to consider in the qualitative 

discussion could include meteorology, terrain, distance to ambient air, expected emissions, etc. 

Ifa convincing case cannot be made qualitatively that no impacts to air quality would be 

expected, a screening analysis should next be performed. 

3. 	 Step 2: Screening Analysis 

For proposed new or modified sources that meet the modeling requirement criteria identified 

above, protection of air quality from proposed emissions may be shown by using a simple 

screening technique (e.g., SCREEN3 or AERSCREEN). Screening models are available for 

download at the EPA SCRAM website: 

http://www.epa.gov/ttniscramldispersionscreening.htm. A pre-approved modeling protocol is 

not necessary prior to conducting a Screening Analysis. 

4. 	 Ifthe proposed new or modified emission increases do not increase ambient concentrations ofa 

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

further modeling is necessary. 

so19D1°filcant I mpact Leve I s 

Pollutant Averaging Period Class II Area SIL 

(uglm3

) 

Class I Area SIL 

(ug/m3) 

S02 

I hr 3 ppb or 7.8 uglm' (interim) ---­

3hr 25 1.0 

24hr 5 0.2 

Annual I 0.08 

PM2.5 

24hr 0.07 1.2 

Annual 0.06 0.3 

PMJO 

24hr 5 0.2 

Annual 1 0.08 

N02 

I hr 4 ppb or 7.5 ug/mj (interim) ---­ Annua1 1 0.08 

CO 1 hr 2,000ppb 

8 hr 500ppb 

• 

• 

• 

Note: The Class 1 area SILs are provided as guidance and have not been formalized by EPA. 

Page \4 of 15 
• 5. 	 Sources that cannot demonstrate protection ofair 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 ofthe model used, all input 

parameters, and the resulting output. Electronic copies of the modeling input/output files should 

be provided to EPA Region 8 . 

./ ESA 

The Endangered Species Act requires us, in consultation with the US. Fish and Wildlife Service 

andlor 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 ofsuch species. 

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

species that you may be readily aware ofthat could be affected by your proposal. The following 

website has been provided to assist you: 

http://www.fWs.gov/endangeredl 

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

• ./ NHPA 

The National Historic Preservation Act requires us, in consultation with State andlor 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 ofthat could be affected by your proposal. The following 

website has been provided to assist you: 

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

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

Page 15 of 15 

• 

• 

UNITED STATES ENVIRONMENTAL PROTECTION AGENCY I: 

Region 8 Air Program 

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY 

Checklist· Synthetic Minor Limit Request 

(Form SYNMIN) 

Use of this information request form is voluntary and not yet approved by the Office of Management and Budget. The 

following is a check list ofthe type ofinfonnation that Region 8 will use to process infonnation on your proposed project. While 

submittal ofthis fonn 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 fonns for this program is currently under 

Office of Management and Budget review and these infonnation request forms will be replaced/updated after that review is 

completed. 

Please submit information to following two entities: 

Company Name 

Dakota-3 E&P Company, LLC 

Facility Name 

Olson-FBIR Pad 

Company Contact or Owner Name 

JoDell Mizoue 

Title 

Staff Environmental 

Specialist 

Mailing Address 

1001 17UJ Street, Suite 1200 Denver, CO 80202 

Email Address 

JoDell.Mizoue@Williams.com 

Telephone Number 

(303) 606-4056 

IFacsimile Number 

: (303) 692-8285 

The Tribal Environmental Contact for the specific reservation: • 

Ifyou need assistance in identifying the appropriate Tribal 

Environmental Contact and address, please contact the EPA 

Region 8 Tribal Air Coordinator: 

Alexis North, EPA Region 8 Tribal Air Coordinator 

303-312-7005 

north.alexis@epa.gov 

• 

• 

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

./ Item 1 - The proposed limitation and a description of its effect on current actual, allowable and the potential to 

emit. 

./' Item 2 - The proposed testing, monitoring, recordkeeping, and reporting requirements to be used to demonstrate 

and assure compliance with the proposed limitation . 

./ Item 3 - A description of estimated efficiency of air pollution control equipment under present or anticipated 

operating conditions, including documentation ofthe manufacturer specifications and guarantees . 

./' Item 4 - Estimates of the Post-Change Allowable Emissions that would result from compliance with the proposed 

limitation, including all calculations for the estimates . 

./ Item 5 - Estimates of the potential emissions of Greenhouse Gas (GHG) pollutants before and after proposed 

emission controls. 

Federal Minor NSR Permit Coordinator 

U.S. EPA, Region 8 

1595 Wynkoop Avenue, 8P-AR 

Denver, CO 80202-1129 

A. GENERAL INFORMATION 


B. ATTACHMENTS 

• 


Instructions 

Use this form to provide general and summary information about the synthetic minor NSR 

source (faciHty or plant) on Tribal lands and to indicate the emissions limitations requested. 

Submit this form once, in addition to FORM NEW, for each synthetic minor NSR source on 

Tribal lands. 

1. Who Can Request Federally-Enforceable Limitations Under the Tribal NSR Authority? 

The Tribal NSR Rule applies only to sources located within the exterior boundaries of an Indian 

reservation in the United States ofAmerica or other lands as specified in 40 CFR part 49, collectively 

referred to as "Indian country". So, to use the authority in the Tribal NSR Rule to create federally­

• enforceable limitations, a facility must be located within Indian country. Land ownership status (for 

example, whether the land is owned by a Tribal member or whether the land is owned in fee or in trust) 

does not affect how the rule applies. 

2. Who Might Want to Request Federally-Enforceable Limitations? 

The primary reason for requesting federally-enforceable limitations is to avoid an otherwise applicable 

federal Clean Air Act program, rule or requirement. Many federal Clean Air Act programs use a 

source's "potential to emit" (PTE) air pollution to determine which rules or requirements apply. A 

facility's PTE is based on the maximum annual operational (production, throughput, etc) rate ofthe 

facility taking into consideration the capacity and configuration ofthe equipment and operations. 

Emission or operational limits can also be taken into consideration as maximums ifthey are federally 

enforceable. So, using a synthetic minor NSR permit to establish federally enforceable limitations can 

lower a facility's PTE and possibly allow the facility to avoid certain federal Clean Air Act 

requirements. 

Three examples of federal Clean Air Act programs that use PTE to determine whether they apply are 

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

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

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

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

Ifa source accepts a federally-enforceable limitation through a synthetic minor NSR permit that 

• reduces their PTE to below the "major" threshold, and the source does not meet any ofthe other 

requirements that would trigger applicability to the part 71 program, then the source no longer needs a 

Title V operating permit. When planning for the construction ofa new source or expansion ofan 

existing source, a source can also accept limitations on PTE (using a synthetic minor NSR permit) that 

allow the source to avoid PSD. Limitations on PTE can similarly help a source to avoid new MACT 

standards that would otherwise apply to the source. 

3. Section B. ATTACHMENTS 

This section lists the information that must be attached to the application form for each requested 

limitation. The requested limitation(s) must be described for each affected emissions unit (or pollutantgenerating activity) and pollutant and must be accompanied by the supporting information listed on the 

form and described below. Note that applicability of many federal Clean Air Act requirements (such as 

Title V, PSD and MACT) is often based on facility-wide emission levels of specific pollutants. In that 

• Page 2 of4 
• 

case, all emissions units at a facility and all pollutants regulated by that given rule or regulation must 

be addressed by this section ofthe application form. 

Item 1 - The requested limitation and its effect on actual emissions or potential to emit must be 

presented in enough detail to document how the limitation will limit the source's actual or potential 

emissions as a legal and practical matter and, ifapplicable, will allow the source to avoid an otherwise 

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

emission unit and each air pollutant from that emission unit. Use the information provided in response 

to Item 4 below to explain how the limitation affects emissions before and after the limitation is in 

effect. 

Item 2 - For each requested limitation, the application must include proposed testing, monitoring, 

recordkeeping and reporting that will be used to demonstrate and assure compliance with the 

limitation. Testing approaches should incorporate and reference appropriate EPA reference methods 

where applicable. Monitoring should describe the emission, control or process parameters that will be 

relied on and should address frequency, methods, and quality assurance. 

Item 3 - The application must include a description and estimated efficiency ofair pollution control 

equipment under present or anticipated operating conditions. For control equipment that is not 

proposed to be modified to meet the requested limit, simply note that fact; however, for equipment that 

is proposed to be modified (e.g. improved efficiency) or newly installed to meet the proposed limit, 

address both current and future descriptions and efficiencies. Include manufacturer specifications and 

guarantees for each control device. 

Items 4 - Any emission estimates submitted to the Regional Administrator must be verifiable 

using currently accepted engineering criteria. The following procedures are generally 

acceptable for estimating emissions from air pollution sources: 

(i) Source-specific emission tests; 

(ii) Mass balance calculations; 

(iii) Published, verifiable emission factors that are applicable to the source. (i.e., manufacturer 


sped fications). 


(iv) Other engineering calculations; or 

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

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

and generally is calculated by mUltiplying the allowed hourly emissions rate in pounds per hour 

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

the number ofpounds in a ton). 

Item 5 - New construction projects that have the potential to emit GHG emissions of at least 100,000 

tpy C02e and 100 or 250 tpy on a mass basis, modifications at existing PSD facilities that increase 

GHG emissions by at least 75,000 tpy C02e and minor sources that increase GHG emissions by at least 

100,000 tpy C02e and 100 or 250 tpy on a mass basis are subject to PSD permitting requirements, even 

ifthey do not significantly increase emissions ofany other pollutant. As such, any requested limits to 

avoid PSD must take into account greenhouse gases. 

Therefore, please include in your permit application estimates ofthe potential emissions ofthe 

following pollutants before and after proposed emission controls. More information about GHG 

permitting and how to calculate C02 equivalents (C02e), the mass emissions ofeach individual GHG 

Page 3 of4 

• 

• 

• 
• adjusted for its Globa1 Warming Potential (GWP) can be found at: 

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

1. Carbon dioxide (C02) 

2. Methane (CH4) and its C02C 

3. Nitrous oxide (N20) and its C02C 

4. Hydrofluorocarbons (HFCs) and its C02c 

5. Per fluorocarbons (PFCs) and its C02e 

6. Sulfur hexafluoride (SF6) and its C02e 

• 

• 

• 

Page 4 Qf4 
• 

OLSON-FBIR PAD ATTACHMENTS: 

• 


Attachment A: Application Report 

Attachment B: Emission Inventory 

Attachment C: Flashing Emissions Calculations 

Attachment D: Representative Low Pressure Oil Analytical Data 

Attachment E: Representative Gas Analysis 

Attachment F: Engine Manufacturer's Specs 

Attachment G: Emission Control Device Manufacturer's Specs 

Attachment H: Process Flow Diagram of Facility 

Attachment I: Production Decline Curve Calculations 

Attachment J: Diesel Tank EPA TANKS 4.09d Emission Summary 

• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 

ATTACHMENT A: APPLICATION REPORT 

• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


• 


APPLICATION FOR AN NSR 


PSD/TITLE V SYNTHETIC MINOR 


AIR QUALITY PERMIT 


OLSON-FBIR 


PAD OIL & GAS 


PRODUCTION FACILITY 


Prepared for: 

Dakota-3 E&P Company, LLC 

100117th Street, Suite 1200 

Denver, CO 80202 

Prepared by: 

Bison Engineering, Inc. 


1400 11th Avenue 


• Helena, MT 59601 


(406) 442-5768 


www.bison-eng.com 


December 29, 2011 

• 

• 

TABLE OF CONTENTS 

1.0 INTRODUCTION .................................................................................................. 1 


1.1 Summary ................................................................................................... 1 


1.2 Site Location .............................................................................................. 1 


1.3 Site Description .......................................................................................... 1 


2.0 NARRATIVE DESCRiPTION ................................................................................ 3 


3.0 POTENTIAL TO EMIT ESTIMATE ....................................................................... 5 


3.1 Production Storage Tank VOC Emissions ................................................. 8 


3.2 

....... 9 


Produced Casing Head Gas Emissions ..................................................... 8 


• 3.3 Reciprocating Internal Combustion or Compression Ignition Engines 

3.4 Natural Gas External Combustion Unit Emissions ..................................... 9 


3.5 Truck Loading Emissions ........................................................................... 9 


3.6 Fugitive Emissions: Dust and Equipment Leaks ....................................... 9 


4.0 EMISSIONS AND OPERATIONAL LIMITS REQUESTS ................................... 10 


4.1 Production Storage Tank Emissions ........................................................ 10 


4.2 Reciprocating Internal Combustion or Compression Ignition Engines ..... 10 


5.0 ALLOWABLE EMiSSiONS ................................................................................. 11 


5.1 Storage Tank Emissions .......................................................................... 11 


5.2 Produced Casing Head Gas Emissions ................................................... 11 


5.3 Rice Engine Emissions ............................................................................ 11 


5.4 Natural Gas External Combustion Unit Emissions ................................... 11 


5.5 Truck Loading Emissions ......................................................................... 12 


5.6 Fugitive Emissions: Dust and Equipment Leaks ..................................... 12 


5.7 Diesel Storage Tank Emissions ............................................................... 12 


6.0 PROPOSED MONITORING AND RECORDKEEPING ...................................... 13 


6.1 Production Storage Tanks ....................................................................... 13 


6.2 Production Storage Tank Emissions Control Device ............................... 14 


6.3 Produced Casing Head Gas Emergency Utility Flare .............................. 16


• 6.4 Rice Engines ............................................................................................ 17 


6.5 Natural Gas-Fired External Combustion Units ......................................... 17 


6.6 Truck Loading .......................................................................................... 18 


6.7 Fugitive Emissions: Dust and Equipment Leaks ..................................... 18 


6.8 General Recordkeeping Requirements .................................................... 20 


7.0 QUALITATIVE AIR QUALITY ASSESSMENT .................................................... 21 


8.0 ENDANGERED SPECIES ACT .......................................................................... 22 


9.0 NATIONAL HISTORIC PRESERVATION ACT .................................................. 23 


Olson-FBIR Pad 12/29/11 pg. ii 


NSR Synthetic Minor Permit Application 


Project #: WEP211324 


• 
• 

FIGURES 


Figure 1: Example of Maximum PTE from a Seven Well Pad ................................... 6 


Figure 2: Example of Actual Production from a Seven Well Pad .............................. 7 


ATTACHMENTS 

Attachment A: 

Attachment B: 

Attachment C: 

Attachment D: 

Attachment E: 

Attachment F: 

Attachment G: 

Attachment H: 

Attachment I: 

Attachment J: 

Application Report 

Emission Inventory Spreadsheets 

E&P Tank V2 Emission Summary Output 

Representative Low Pressure Oil Analytical Data 

Representative Gas Analysis • 

Engine Manufacturer'S Specs 

Emission Control Device Manufacturer's Specs 

Process Flow Diagram of Facility 

Production Decline Curve Calculations 

Diesel Tank EPA TANKS 4.09d Emissions Summary 

• 

• 

Olson-FBIR Pad 12/29/11 pg. iii 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


• 


• 


• 


1.0 INTRODUCTION 


1.1. Summary 

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

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

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

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

Air Act. 

Dakota-3 is proposing to construct and operate the Olson-FBIR Pad Oil and Gas (O&G) 

production facility on the FBIR. Included in this application for a synthetic minor permit 

are allowable emissions specified by requested federally enforceable permit conditions 

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

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

1.2. Site Location 

The Olson-FBIR Pad is proposed to be located in the northwest y.. of the northeast y.. 

Section 13, Township 150 North, Range 92 West, Mountrail County, on the FBIR in 

North Dakota. 

1.3. Site Description 

At the proposed Olson-FBIR Pad there will be seven oil and gas wells that are proposed 

to produce to the facility. The facility will be situated on an approximately ten acre site, 

with an elevation of approximately 2,000 feet (mean sea level), in Mountrail County, 

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

The proposed pad's associated well names are: 

1. Olson 12-1HX 

2. Olson 12-1 HC 

3. Olson 12-1HY 

4. Olson 12-1HD 

5. FBIR 13-24HC 

6. FBIR 13-24HD 

7. FBIR 13-24HZ 

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

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

names change. 

Olson-FBIR Pad 12/29111 pg.1 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 

2.0 NARRATIVE DESCRIPTION 


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

Olson-FBIR Pad. For purposes of estimating emissions from this facility, the combined 

first twelve-month potential production from the seven proposed wells at this facility was 

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

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

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

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

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

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

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

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

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

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

at different times. 

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

capabilities. 

7 - Heater Treater/Separators 7 - Line-Heaters (0.75 MMBtu/hr max) 

35 - Oil Production Tanks 1 - Gasoline Recycling Pump 

14 - Produced Water Tanks 7 - Electric Lifting Units 

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

1 - Manufactured Produced Gas Flare 7 - Diesel Engines 

1 - Manufactured Enclosed Tank Vapor Combustor 

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

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

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

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

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

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

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

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


•

phases from each other because of differences in densities. The line-heater is fueled by 


onsite produced caSing head gas that is routed to the heater's combustion chamber. 


Propane may also be used as an alternative fuel if necessary. Following the heater 


treater the oil and water are routed to their separate storage tanks. 


The produced casing head gas is transferred from the two-phase separators to the 


sales gas pipeline. An onsite utility flare serves as an emergency backup in the event 


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


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


device. The stored oil is transported for sale via the truck loadout. Produced water is 


• 

Olson-FBIR Pad 12/29/11 pg.2 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


stored in the onsite water storage tank until it is transported offsite using the water 

pipeline. 

At the facility, there is a small gasoline fueled pump located near the production storage 

tanks. This pump is commonly known as a "transfer" or "recycle." The pump is used to 

periodically recycle the liquids (oil/water) in the bottom of the production tanks back into 

the heater treater for further separation. Otherwise, the facility is completely electrified; 

however, the electricity lines have not yet been installed at the facility. Onsite diesel 

genset engines will provide electricity until transmission lines are installed. 

A process flow diagram and plot plan of the site is shown in Attachment H. 

• 

• 

Olson-FBIR Pad 12/29/11 pg.3 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

3.0 POTENTIAL TO EMIT ESTIMATE 


In estimating the average production for the first twelve months. a decline curve was 

developed. The decline curve takes into account the fact that the initial production of the 

well will greatly decline over the initial twelve months of production. Assuming that each 

well's production would be equivalent to the initial production will grossly overestimate 

production and is not realistic for how an oil and gas well operates. The decline curve 

calculated for this facility was developed using existing well data from wells previously 

drilled and producing in the same region. The confidential decline curve estimations are 

included in Attachment I of the application. 

As noted in Section 2.0 above, determination of potential emissions from the proposed 

facility has been approached in a very conservative fashion. The combined production 

rate for the pad assumes all of the wells start production simultaneously (represented in 

example Figure 1). With this assumption, the initial 3D-day production from each well is 

summed to estimate a potential total production rate from the pad. Operating practice is 

that the wells will be drilled over time. often months or even years apart. Further, after 

each well is drilled and brought into production. the initial production rate generally 

decreases greatly before the next well is drilled. Therefore, this potential to emit (PTE) 

estimate is meant only to define an outer envelope of emissions for permitting 

applicability purposes. Furthermore, the allowable emissions estimates presented in 

Section 4 are also very conservative compared to anticipated actual emissions that 

could be emitted at the facility during any given 12-month rolling average. An example 

demonstrating the predicted production of a theoretical multiple well pad over an 

extended period of time is presented in Figure 2. This example does not represent 

predicted production from the well pad being permitted in this application; however, it 

does serve to demonstrate typical operations for this type of facility. 

• 

• 

• 

Olson-FBIR Pad 12/29/11 pg.4 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• • • • 

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

Example of Maximum PTE from a Seven Well Pad 

6,000 

• 	 All seven wells begin 


production
 5,000 simuftaneous1v­

~,ooo . •

CD •

1,000 • 

t 

lilt 

.­

• 	 Total Production from seven 

w~nson Pad

:1,000 ~ • ---*..-	 ­

~~ •••••••••••! ......... 
 1,000 

o 

o 	 10 20 30 40 


Month 


Olson-FBIR Pad 12/29111 pg.5 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• • • • 

Figure 2: Example of Actual Production from a Seven Well Pad 

Example of Actual Production From a Seven-Well Well Pad 


3,500 

" 6th and 7th wells begin 

production 

3,000 

2,500 

Q 

0. 

Ii 

II 2,000 

! 

l 

5th well begins production 

2nd well begins production 

1st well begins production 

~Total Production from Seven Wells on Pad 

~ ---12-Month Roiling Average Oil Production 

-= 1,500 c -12-Month Rolling Average Oil Production limit o 

~ 

1,000 

500 

o 

o 5 10 15 20 25 30 35 40 

Month 

Olson-FBIR Pad 12/29111 pg.6 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


Potential emissions from this facility originate primarily from the heater treater lineheaters emissions, the production storage tank uncontrolled emissions, truck loading 

emissions, diesel genset emissions, and fugitive emissions (e.g., truck loading, 

equipment leaks and road dust). The maximum design capacity of the engines and 

natural gas-fired external combustion units, in conjunction with maximum annual 

anticipated oil and gas production rates of this facility, were used in determining the 

facility's potential to emit (PTE). The oil, gas, and water production rates were estimated 

by using data from recently drilled wells in the same region and extrapolating the rates 

for this proposed pad. 

• 

The potential emissions are stated in the Application for New Construction (Form NEW), 

Table E(i) - Proposed New Facility. The emissions from the facility fall into the following 

categories (Le., emitting units). 

1. 	 Production Storage Tanks (Oil and Water); 

2. 	 Casing Head Gas (Produced Gas); 

3. 	 Reciprocating Internal Combustion Engines (Recycle Pump Engine and 

Diesel Gensets) 

4. 	 Natural Gas External Combustion Units (Heater Treater Line-Heaters); 

5. 	 Truck loading 

6. 	 Miscellaneous Fugitive Emissions (Fugitives); 

3.1 Production Storage Tank VOC Emissions 

To estimate the uncontrolled PTE of the production tank's vapors (working. breathing, 

standing, and flashing), extended BTEX low pressure oil analyses were taken from 

representative wells producing out of the same geological region. E&P Tanks V2 was 

used to calculate the production tank's vapors using the anticipated maximum 

production rates, area-specific ambient pressure/temperature data, representative 

process operating conditions, and sampled analytical data. The E&P Tanks output 

summary includes all of the needed input data in the emission inventory, such as the 

vapor rate that is produced from the tanks (scf/bbl), the mol% of the vapor components. 

such as VOCs, HAPs, GHGs, etc. 

• 	 All applicable uncontrolled emissions from the storage tanks calculations, low pressure 

analytical data, and E&P TANKS program inputs and outputs are provided in the 

attachments. 

3.2 Produced Casing Head Gas Emissions 

At the two-phase separator, +90% of all of the initial casing head gas is separated and 

sent to the gas sales pipeline. After the initial separation occurs, the leftover emulsified 

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

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

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

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

Olson-FBIR Pad 12/29111 pg. 7 

NSR SynthetiC Minor Penn it Application 

Project #: WEP211324 

• 
• 

pressure increases to the pOint at which the produced casing head gas from the twophased separator cannot be sold or the gas pipeline has a malfunction, the flare serves 

as an emergency backup. 

3.3 Reciprocating Internal Combustion or Compression Ignition Engines 

Diesel engines connected to generators provide the facility with electricity. The potential 

emissions from the engines are estimated by assuming the engine is operating 8,760 

hours per year and applying the federally required 40 CFR 63 Subpart JJJJ or 40 CFR 

60 Subparts 1111 and ZZZZ emission limits as applicable. 

3.4 Natural Gas External Combustion Unit Emissions 

The natural gas external combustion units at the facility are the heater treater lineheaters. Each heater is rated to a maximum capacity of 750,000 Btulhr. The emissions 

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

3.5 Truck Loading Emissions 

Oil sales and water pipelines are planned for this facility in the future; however, since 

the pipeline infrastructure has not yet been constructed, the facility is not anticipated to 

be hooked to the oil sales pipeline in the near future, and the produced oil and water will 

be trucked from the facility. The emissions associated with the truck loading operations 

will be estimated using daily production, AP-42 factors, and submerged fill loading 

without any control. 

3.6 Fugitive Emissions: Dust and Equipment Leaks 

Fugitive emissions from equipment leaks and dust are not required to be estimated for 

purposes of potential to emit within the NSR permitting program. However, the fugitive 

emissions will be estimated after a final permit is issued and production begins in order 

to track to the twelve-month rolling average actual emissions. The fugitive leak 

emissions primarily consist of leaks from connectors, open-ended lines, valves, pumps, 

etc. These emissions will be estimated using EPA's average emissions factors for total 

hydrocarbon emissions from O&G production operations. The fugitive dust emissions 

will be estimated using AP-42 factors to capture the emissions associated with vehicle 

traffic at the location. 

• 

• 

Olson-FBIR Pad 12/29/11 pg.8 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

4.0 EMISSIONS AND OPERATIONAL LIMITS REQUESTS 

Oatoka-3 is requesting emissions and operational limits at the Tracy 15H Pad in order to 

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

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

emitting less than the PSOrritle V major source thresholds of 250/100 tons per year of a 

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

of all emitted HAPs. 

4.1 Production Storage Tank Emissions 

• The majority of emissions associated with the facility occur from the working, breathing, 

standing. and flashing vapors from the production storage tanks. Therefore, Oakota-3 

will control the storage tank VOC and HAP emissions by installing an enclosed 

smokeless combustion device that has been independently tested and certified to 

exceed the requirements of 40 CFR 60.18 at 98% destruction efficiency (ORE). 

Although this control device is certified to meet 99% ORE. Oakota-3 will assume the 

minimum required 98% ORE for purposes of calculating the controlled tank vapor 

emissions. This control device will allow Oakota-3 to apply a 98% control efficiency to 

the uncontrolled PTE. On this basis, the requested emission limit from the storage tanks 

is: 35.13 tons per year of VOCs and 0.33 tons per year of HAPs. 

4.2 Reciprocating Internal Combustion or Compression Ignition Engines 

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

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

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

1111 and Z:ZZZ, as applicable. 

• 

Olson-FBIR Pad 12/29/11 pg.9 

NSR Synthetic Minor Pennit Application 

Project #: WEP211324 

• 
• 

5.0 ALLOWABLE EMISSIONS 


The allowable emissions are the new estimated controlled potential to emit based on 

the federally enforceable controls and limits requested in Section 4. The allowable 

emissions are also presented in the Application for New Construction (Form NEW), 

Table E(i) - Proposed New Facility. 

5.1 Storage Tank Emissions 

The storage tank controlled emissions are estimated by applying 98% control efficiency 

to the uncontrolled VOC, HAP, and CH4 emissions. Although the VOC, HAP, and CH4 

emissions are reduced by the smokeless combustion device, CO, NOx, PM, PM1Q, PM2.5 

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

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

pollutant and greenhouse gas components from a representative gas analysis. 

5.2 Produced Casing Head Gas Emissions 

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

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

heater treater will be sent to the onsite utility flare. Furthermore, if the gas sales pipeline 

pressure increases to the point at which the produced casing head gas from the twophased separator cannot be sold or the gas pipeline has a malfunction, the flare serves 

as an emergency backup. No limits have been requested for the produced casing head 

gas emissions at the facility; therefore, the emissions estimate is equal to the potential 

to emit. 

5.3 RICE Engine Emissions 

No limits have been requested for the RICE at the facility. Oakota-3 is required to meet 

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

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

emit. 

5.4 Natural Gas External Combustion Unit Emissions 

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

MMBtu/hr heater treater line-heaters) at the facility; therefore, the emissions estimate is 

equal to the uncontrolled potential to emit. 

• 

• 

• 

Olson-FBIR Pad 12/29/11 pg. 10 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• 


5.5 Truck Loading Emissions 

No limits have been requested for the truck loading operations at the facility; therefore, 

the emissions estimate is equal to the uncontrolled potential to emit. 

5.6 Fugitive Emissions: Dust and Equipment Leaks 

Fugitive emissions from equipment leaks and dust are not required to be estimated for 

purposes of potential to emit within the NSR permitting program. However, the fugitive 

emissions will be· estimated after a final permit is issued in order to track the twelvemonth rolling average actual emissions. The fugitive leak emissions primarily consist of 

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

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

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

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

5.7 Diesel Storage Tank Emissions 

There will be an onsite storage tank at this facility to store diesel fuel that will be utilized 

in the diesel gensets. This tank will be either a horizontal or vertical 1,000 gallon tank. 

Emissions for this tank were estimated using EPA TANKS 4.09d and determined to be 

less than 0.01 tpy. Because of the low level of emissions from this equipment, it has 

been determined to have insignificant emissions. The EPA TANKS 4.09d emissions 

summary output is in Attachment J. 

• 


• 


Olson-FBIR Pad 12/29111 pg. 11 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
6.0 PROPOSED MONITORING AND RECORDKEEPING 


• 

• 

As per the Application for Synthetic Minor Limit Request (Form SYNMIN), Page 1 (B), 

ATTACHMENTS, Item, 2, Datoka-3 is required to propose testing, monitoring, 

recordkeeping, and reporting requirements that will be used to demonstrate and assure 

compliance with the proposed allowable emissions. 

6.1 Production Storage Tanks 

The production storage tanks will have their flashing and standing/working/breathing 

vapors routed by a closed-vent system to equipment deSigned to capture the VOC and 

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

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

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

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

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

requested proposed device(s): 

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

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

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

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

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

or an emissions control device; and 

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

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

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

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

Monitoring Requirements: 

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

one of the following methods: 

a. 	 Direct measurement of standing/working/breathing losses by sampling and lab 

analysis; 

b. 	 EPA TANKS 4.0.9d to calculate standing/working/breathing losses; 

c. 	 Direct measurement of flashing emissions by sampling and lab analysis; 

d. 	 Process simulator such as PROMAX, HYSIM, HSYS using site-specific sampling 

and lab analysis to calculate flashing emissions in conjunction with EPA TANKS 

4.0.9d to calculate standing/working/breathing losses; 

e. 	 API E&P TANKS Software V2.0 using representative sampling and lab analysis 

to calculate standing/working/breathing losses and flashing emissions; or 

f. 	 Other methods approved by EPA. 

• 

Olson-FBIR Pad 12129/11 pg. 12 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


Recordkeeping Requirements: 

Total VOC, total HAP, and any single HAP emissions, in tons, from production storage 

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

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

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

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

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

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

months and record a new twelve-month total. 

• 

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

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

6.2 Production Storage Tank Emissions Control Device 

The limits requested on the emissions from the storage tanks are directly dependent on 

the production throughput in the tanks. All emissions at the facility will be controlled in 

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

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

the device by at least 98%. 

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

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

ensure good air pollution control practices for minimizing emissions. 

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

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

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

Each enclosed combustion device will be: 

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

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

• 	 b. Operated with a liquid knock-outsystem to condense any condensable vapors; 

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

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

in °C, or ±2.S °C; 

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

document the presence of a flame; 

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

alarm and remote notification system if the pilot flame fails; 

f. 	 Maintained in a leak-free condition; and 

g. 	 Operated in a smokeless mode. 

Olson-FBIR Pad 12/29/11 pg. 13 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
Monitoring Requirements: 

Oakota-3 will identify, via an independent engineering analysis or a manufacturer or 

vendor guarantee, each control device's operating parameters within which they will 

meet the 98.0% reduction requirement. Oakota-3 will monitor the control device 

operations to confirm proper operation as follows: 

a. 	 Monitor the pilot flame using a thermocouple and a chart recorder that indicates 

the continuous ignition of the pilot flame; 

b. 	 An inspection of the chart recorder to ensure proper operation will be done 

whenever an operator is on site; at a minimum, quarterly; 

c. 	 A visual inspection of the pilot flame to ensure proper operation will be done 

whenever an operator is on site; at a minimum, quarterly; 

d. 	 Measure one other parameter determined during the independent engineering 

analysis or provide a manufacturer or vendor guarantee; and 

e. 	 Visually confirm that no smoke is present during operation of any enclosed 

combustor or utility flare whenever an operator is on site; at a minimum, 

quarterly. 

Recordkeeping Requirements: 

• 

• 

a. Records will be kept of the site-specific design input parameters provided for the 

independent engineering analysis or provided to the manufacturer or vendor and 

used to properly size the enclosed combustors and utility flares to assure the 

98% reduction requirements. 

b. Records will be kept of all required monitoring of the control device operations. 

c. Records will be kept of any instances in which any control device was bypassed 

or down in each calendar month, the reason for each incident, its duration, and 

the corrective actions taken or the preventative measures adopted to avoid such 

bypasses or downtimes. 

d. Records will be kept of the any exceedance of the operating parameters 

specified in the manufacturer or vendor guarantee or engineering analysis and 

selected for the required monitoring. The records will include the enclosed 

combustor's total operating time during the calendar month in which the 

exceedance occurred, the date, time and length of time that the parameters were 

exceeded, and the corrective actions taken or the preventative measures 

adopted to operate the facility within that operating parameter. 

e. Records will be kept of any instances in which the pilot flame is not present in the 

enclosed combustor or the utility flare, the date and times that the pilot was not 

present and the corrective actions taken or the preventative measures adopted to 

increase the operating time of the pilot flame. 

f. Records will be kept of any instances in which the thermocouple (or other heat 

sensing monitoring device) installed to detect the presence of a flame in the 

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

it was not operational, and the corrective measures taken. 	

• 

Olson-FBIR Pad 12/29/11 pg.14 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


UNITED STATES ENVIRONMENTAL PROTECTION AGENCY 


Region 8 Air Program 


FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY oEPA 

Check List - Application for New Construction 

(FonnNEW) 

Please check all that apply to show how you are using this form 

• Proposed Construction of a New Facility 

o Proposed Construction of New Equipment at an Existing Facility 

o Proposed Modification of an Existing Facility 

o Other - Please Explain 

Use of this information request form is voluntary and not yet approved by the Office of Management aDd Budget 

• 

The following is a check list ofthe type of information that Region 8 will use to process information on your proposed 

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

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

this program is currently under Office 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: 

Ifyou need assistance in identifying the appropriate Tribal 

Environmental Contact and address, please contact the EPA 

Region 8 Tribal Air Coordinator: 

Alexis North, EPA Region 8 Tribal Air Coordinator 

303-312-7005 

north.alexis@epa.gov 

A. GENERAL FACILITY INFORMATION 


• 


1. (a) Company Name 

Dakota-3 E&P Company, LLC 

(b) Operator Name 

Dakota-3 E&P Company, LLC 

2. Facility Name 

Olson-FBIR Pad 

3. Type ofOperation 

Oil and Gas Production 

4. Portable Source? o Yes rgj No 

5. Temporary Source? 0 Yes rgj No 

6. NAICS Code 

213111 

7. SIC Code 

1311 

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

9. Reservation* 

FBIR 

10. County* 

Mountrail 

11a. Latitude* 

47.81687 

11b. Longitude* 

-102.39371 

12a. Quarter Quarter Section* 

NWNE 

12b. Section* 

13 

12c. Township * 

TISON 

12d. Range* 

R92W 

• 

Facility Name on the Permit N/A 

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

I Date ofthe Permit Action N/A 

• 

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

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

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

no previous permit actions have been taken. 

• 

• 

• 
• 


• 


• 


• 


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

emanating from an enclosed combustor or utility flare. 

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

include the following: 

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

ii. 	 Date( s) analyses were performed; 

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

iv. Analytical techniques or methods used; 

v. 	 Results of such analyses or measurements; and 

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

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

means that indicates the continuous ignition of the pilot flame; 

j. 	 A check of the chart recorder or other monitoring device to ensure proper 

operation will be done whenever an operator is on site; at a minimum, quarterly; 

k. 	 A check of the pilot flame to ensure proper operation will be done whenever an 

operator is on site; at a minimum, quarterly; 

I. 	 Measure one other parameter determined during the independent engineering 

analysis or provide a manufacturer or vendor guarantee; and 

m. 	Visually confirm that no smoke is present during operation of any enclosed 

combustor or utility flare whenever an operator is on site; at a minimum, 

quarterly. 

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

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

ensure good air pollution control practices for minimizing emissions. 

6.3 Produced Casing Head Gas Emergency Utility Flare 

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

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

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

flare . 

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

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

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

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

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

practices for minimizing emissions. ' 

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

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

maintained and operated during any time the facility is operating. 

Olson-FBIR Pad 12/29111 pg,15 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
The emergency utility flare will be: 

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

and 40 CFR 63.11. 

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

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

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

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

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

in °c, or ±2.5 °C; 

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

document the presence of a flame; 

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

alarm and remote notification system if the pilot flame fails; 

g. 	 Maintained in a leak-free condition; and 

h. 	 Operated in a smokeless mode. 

Monitorinq Requirements: 

The monitoring requirements for the emergency utility flare will be the same as 

described above for the production storage tanks control device as specified in Section 

6.2. 

Recordkeepina Requirements: 

The recordkeeping requirements for the emergency utility flare will be the same as 

described above for the production storage tanks control device as specified in Section 

6.2. 

6.4 RICE Engines 

Depending on the size (hp) and date of manufacture, Dakota-3 is required to meet the 

emission standards set forth in 40 CFR 63 Subpart JJJJ or 40 CFR 60 Subparts 1111 and 

1212, as applicable. Dakota-3 will properly operate and maintain the engines as per the 

manufacturer's specifications to ensure compliance with the above standards. If the 

engines emissions are not certified to meet the required standards, Dakota-3 will have 

performance tests conducted on the engines as required by the applicable subparts. 

6.5 Natural Gas-Fired External Combustion Units 

Due to the insignificant emissions associated with the 0.5 to 0.75 MMBtu/hr natural gas 

(or propane) fired line-heaters, no monitoring or recordkeeping requirements are being 

proposed by Dakota-3. 

• 

• 

• 

Olson-FBIR Pad 12/29/11 pg.16 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


6.6 Truck Loading 

The truck loading rack is designed for submerged filling of the tank trucks. This is 

standard operating procedure. 	 i 

I 

Monitoring Requirements: 

The monitoring requirements for truck loading will be estimating the monthly VOC, total I HAP, and any single HAP emissions from the loadout operations using input 

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

Chapter 5. 	 I

I 

Recordkeeping Reguirements: t • 	 ~ 

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

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

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

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

calculated emissions for all previous months since operations commenced, where 

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

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

months and record a new twelve-month total. 

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

emissions. 

6.7 Fugitive Emissions: Equipment Leaks 

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

hydrocarbon service at this facility. 

Work Practice and Operational Requirements: 

• 

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

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

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

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

collect vapors and transport them. 

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

days after the leak is detected. 

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

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

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

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

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

Olson-FBIR Pad 12/29/11 pg.17 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 

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


piece of equipment in hydrocarbon service at this facility. 


Monitoring Requirements: 

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


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


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


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


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


annual. 


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


equipment: 


i. Method 21 • 

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

Appendix A-7, Method 21; and 

b) If an instrument reading of 10,000 ppm or greater is measured, a leak 

is detected. 

ii. 	 Optical Gas Imaging Instrument 

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

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

Alternative work practice for monitoring equipment leaks; 

b) Any emissions detected by the optical gas imaging instrument are a 

leak unless screened with Method 21 (40 CFR Part 60, Appendix A-7) 

monitoring, in which case 10,000 ppm or greater is designated a leak; 

c) The optical gas image will include an image of the equipment in 

addition to any observed leaks; and 

d) The optical gas imaging instrument will be operated in accordance with 

the instrument manufacturer's operating parameters. 

iii. 	 Operator Developed Inspection Protocol- 'Best Management Practices 

a) Develop and use a written inspection protocol approved by EPA, 

based on best management practices, for leak detection; 

b) Any emissions detected by the protocol are a leak unless screened 

with Method 21 (40 CFR Part 60, Appendix A-7) monitoring. in which 

case 10,000 ppm or greater is designated a leak; 

c) 	 The protocol will include the following: • 

I. 	 A detailed description of the best management practice to be 

used for leak detection; 

II. 	 A requirement to use a log book that contains a list, summary 

description, or diagram showing the location of all equipment in 

hydrocarbon service at the facility, and the required 

recordkeeping for equipment leaks; and 

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

completion of each inspection. 

Recordkeeping Requirements: 

Olson-FBIR Pad 12/29/11 pg.18 


NSR Synthetic Minor Pennit Application 


Project #: WEP211324 


• 
• 


a. 	 Dakota-3 will document and maintain a record of each leak detection inspection 

and repairs. 

b. 	 All leak detection inspection records will include, at a minimum, the following 

information: 

i. 	 Date of the inspection; 

ii. 	 All documentation and/or images produced in the inspection; 

iii. 	Findings of the inspection; 

iv. Any corrective action taken; and 

v. 	 Inspectorfs name and signature. 

6.8 Genera) Recordkeeping Requirements 

• Total VOC (or VOC, total HAP, and any single HAP) emissions, in tons, from each piece 

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

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

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

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

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

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

months and record a new twelve-month total. 

J 

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

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

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

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

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

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

• 


Olson-FBIR Pad 12129111 pg. 19 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
7.0 QUALITATIVE AIR QUALITY ASSESSMENT 


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

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

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

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

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

that can minimize the effect of air mass movement. 

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

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

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

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

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

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

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

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

industrial activity (although industrial activity is clearly nearby). 

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

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

is not warranted. 

• 

• 

• 

Olson-FBIR Pad 12/29/11 pg.20 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
• 


8.0 ENDANGERED SPECIES ACT 


The Endangered Species Act (ESA) requires EPA, in consultation with the U.S. Fish 

and Wildlife Service (USFWS) and/or the NOM Fisheries Service, to ensure that 

actions EPA authorizes are not likely to jeopardize the continued existence of any listed 

threatened or endangered species (TES) or result in the destruction or adverse 

modification of designated critical habitat of such species. 

lES are considered to be those species recognized by the USFWS as listed or 

proposed species, and those designated as candidate lES under the ESA. Whether 

critical habitat for TES exists near the facility will first be assessed by consulting the 

USFWS North Dakota Ecological Service Field Office website

• (http://www.fws.gov/northdakotafieldoffice/index.htm) and noting the potential 

occurrence of each TES by county. Once the potential presence of a species is 

assessed, a look at whether any critical habitat exists in the vicinity of the facility will 

help determine the possibility of any impacts from the facility on TES. EPA will conduct 

an evaluation of the potential for TES impacts from the facility and consult, as 

appropriate, with USFWS regarding identification and mitigation of any impacts. 

• 

Olson-FBIR Pad 12129111 pg.21 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 

• 
9.0 NATIONAL HISTORIC PRESERVATION ACT 


• 

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

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

affect cultural resources. 

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

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

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

information from the area immediately surrounding the facility 

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

analysis of the immediate area of the facility. a Class II or '" cultural resources inventory 

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

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

and any needed mitigation measures for those impacts. 

• 

• 

Olson-FBIR Pad 12/29/11 pg.22 

NSR Synthetic Minor Permit Application 

Project #: WEP211324 
• • 

Facility Information 

1 

01son.FBlR Pad 

Associated Wells: 

,Olson 12·1HX, 12·1HC 12·1HY, 12·1HO, FBIR 13·24HC. 

13.24HZ, 13·24HO 

Not Producing Yet 

nData 

BOPD 

~ 

Decline Factor 

Adjusted BOPO 

Adjusted Produced Gas (t.IIscfd) 

22 

.E!!. 

0.505 

27011 

1880 

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

.....:;::.:::.;....__..._ml on 

, pIOCIucIIoIIlrI of011 pol' cloy \IIOPIlI.1NIHd 0\1 the pnodIcIod IIIIt30...,. of P'O'IucUon. 

[JIll IttIIe ....... 1IOPO to III procIucod 1111..tile .....................f8ctor. 

tn.....tile .....PIoIodIllOtl of IJII tho ...It tlCpICIIId to P'O'I-IIIIng tile .....................f8ct0r. 

• 
 •

Dakota-3 E&P Company, LLC 

Input Data 


GREEN =Requires input 


OlllCondell8ate Tlnk Data DHc:rlptlon 

Flash Gas Method: Procass Simulator ~"""'down ....U toe""""" tho """"'prIMo ....hIJII moIIIod. 

Process Simulator Estirneted scflbbl 41.57 fTheocflbbl"""'dllllCl ......_or~........ a-on .""'__E&P Tlllk E_1on Su.....ryOutput. 

Estimated Tank Vapors (scfd) 112.c.41.481!'h.... tile MlIIIIIIId ICfd oIlInIt WPOIll blood 0\1 tllelllllowlllCl: tdJlIIIod BOPO mulllpW by tile tcflIbbl ........ on Uno •• 

Lower Heating Value 2395.38 IL-h-.a......(BIuIIdI ofllllkYlpOIlI. a-on .............ESPT••k ~Ion IhrmrrIory Output.

Molecular Weight 41.99 IMoIocuIorwolgirtoftllellnlt WPOIlIIn ,011liii0 pol' ,o...........Io(blHrlalo). a-on ESP Tonk ~Ion SU""""!Y Output. 

VOC% 76.568 ~_""hlfnICIIon ofthellllkwpo'lJII (C3+', a-on ...._ ESP Took E~ Output. 

VOC TPYIBOPD Emission Factor 0.649 on .............ESP Tlllk~ su.....ryOutput. (Iu""""!YOuIput ........IIrIoor roIoIIo.. bIMMn TPV IIIId BOPD) 

HAP% 

HAP TPYIBOPD Emission Factor 

0.718 

0.006 

woIgIrtfnlCllon oftllellnltwpor.... a-on........_ ESP Tonk IhrmrrIory 0UIput. 

~on""",,- ESP Tonk~ su.....ryOUlput.(Iu""""!YOuIput-.-roIoIIo..hlpblMMn TPY IIIId BOPD) 

C02% 0.23% woIghIfnICIIon 01 the lInIt WIPOf IJII. a­ "" ........_ ESP T..k ~Ion SU""""IY 0uIput. 

CH4% 1.59% ~""hlfnICIIonoftlle""kWlPOfIJll. a-"" __E&PT"'~ ........ry()ujput. 

H~weight% 0.16% ....ht_ntoftlleIlnkWlPOf"" a-on........_ ESP T..kE_lonlhrmrrloryOulput. 

H~moIe% 0.20% ~molt_ntoftllellnkwpor lJII.a-on~ESPT..k~IonSumIlllllYOutput. 

Enclosed Smokeless Combustor ~the .............110 chrmetlle.........,nolo ......IonCOl'llllllwe. 

Control Destruction Efficiency 98% ~""'I elllcloncy of lIlY oppIIcabIo _hit. ThIt It.tIad numblr INIHd on.....trol we. 

..... tf .<4_~,~1WI~ II )1_ 11: '11'~! It'W( ,..",~~~ 
• • 

nnuUUOakota_3 E&P Company, LLC 

Input Data 

GREEN =Requires Input 

Facility RED =No input required. This is a caleulated value. Infonnatlon 

Olson·FBIR Pad 


Associated Wells: 


Olson 12.1HX, 12.1HC 12.1HY. 12-1HD. FBIR 13.24HC, 


13·24HZ.13·24HD 
 [.~-.......­

Treater Gal Data Description 

Btu/act 1814.20 BtuIocf of ........po. (F1OIII"'~"""po"lIj 

Molecular Weight 31.69 A....moIoc.welghtol tho.........po In ...........(F............-"""po....l 

Specific Gravity 1.09 if_tilco_opocIfto~tII .......wt/gIIt, ....'thoopoclfto~oItho ......mpo. (F- ~"floldpo"lIl 

Average Molecular Weiaht 31.69 (From..,_tIoId........., 

VOC% 50.99% WCwolghl_.oftho.....-po(llot.:WtIgh!!I..notlilllll'Ao~ (From..,_tIoIdg••""",II) 

HAP% 0.72% HAP IMIghi frIotIon 01 tho.........a•. (!lot.:w.Ight'Ii. not MoII'IIoj. (F...... ..,-"""" _Iytloll 

C02% 0.770"10 CO2 welghtfrlotlon 01 tho .......",...... (IIot.: w.Ight'l!., not "'101",. (From ..__""" .... _Iytloll 

CH4% 21.422% CH....lghtfrlotlonoltho ............. (IIot.:WolgIoI'II.notlllolo'll~ (F..................."""po..III 

H:zS weight % H,S ..lghlp"rconIoftho.. ..... (F...... "'__tIoIdv- • ....,., 0.000"10 

H2S mole % 0.000"10 H,S ..... percontoltho.......",...po. (F...... ....--tIoIdpo."""'.., 

Connected to &ales line UN tho dIop down IMIIU to ct.o.l tho .."....pr\III ......1on control tvPI. 

ControVCapture EffICiency 100% ",uIod til P ..... .., allUlllld 1_captu", of ....IIIInId, _1.....1onoy of any.......,.... _III(co.........,. pIno.., .allyIII... ole,.


Treater Bumer{s) DescrIption 

.w bu""" I1IIIna Ior!hl '--_bul'Mlf.11n 1Ituh-. rlhlro ""' mulllpll bulIIIII, odd!hlliDllll hullnputtoaolhlr. 

Hours of Operation 

Totel Btu/In 

Temperature 

Load Rate (bbVhr) 	

• 

5250000 

50.00 

180 

8780 Th' bul'Mlflllllllro aaUlNld to __1,710 haunt ..... _.

Truck Loading Description 

Oil is hauled by truck UN !hi draD down IMIIU to cIIooR tho 'DDIIlIIriIIIo 01 ..... 1IIIfhod.1'o1 II oold .......... I !.ACT no In_ut ...... I .. "",olrod In Lin.. 3D-35. 


Submel'lled loading: dedicated normal service 0.6 	 UN !hi dIop down lilttil ct.o.l!hliPP"'........ modo ofopellllon. The _lIotIon fIcIor ...lutallllllcdy ba uIocIod b..... on modo 01 ope_•. 


Molecular Weight IIIoIoIcWorwelghtolllnllWipO'"In ..........AD....... __ ............weIght.llahlncl __fIo ......--Ell' T.n"" __
 41.99 

Vapor Prassure lUI WipO' __01 liquid IoIdod, _nelli_or_inchIIbIoIuII (pili'" no ...opecIftr:dtIt II ........... pIoao """,til Tobie 2o. TlUCk Laldlng bib. 


oIbulkllquldloldlclln FIhmIhd. Ifno ...opecIftr: dtIt Ie -a.IIII, _ .......-............~. 

1.OId,.01 liquid 1oIdIcI1n ..... pit hour. 


Load Time (hrs) 


2.30 

1.00 Tht....ltlllooo 10 ....ut_.... (In~ 

IPnaumatic Pumps and Contollenl (None) 

IGIycoI Dehydrator (None) 

• 
• 
 • • 

FacUlty: 

OIson.FBIR Pad 

"""'oclated Wells: 

!Olson 12·1HX. 12·1HC 12· 

1HY. 12.1HD. FBIR 13-201HC. 

13~4HZ, 13·24HD 

Oil/Condensate Tanks 

Casing Head Gas 

Treater Burner 

RICE Engine 

Truck Loadina 

Fuel Storalle Tank 

Pneumatic Pump 

Pneumatic Controllers 

Glycol Dehydrator 

HOx PM10 PM2.5 CO 

N/A NlA N/A NlA 

4.23 0.26 0.26 23.03 

2.25 0.17 0.11 1.89 

30.44 0.18 0.18 50.26 

N/A NlA N/A N/A 

N/A NlA N/A N/A 

N/A NlA N/A N/A 

N/A NIA N/A NlA 

N/A N/A N/A N/A 

HAP 

0.33 

0.50 

0.04 

1.19E-Ol 

0.21 

Negligible 

N/A 

N/A 

N/A 

• 

S02 

N/A 

0.00 

0.01 

1.45E-Ol 

N/A 

N/A 

N/A 

N/A 

N/A 

'Totals (TPY) 

OIl/Condensate Tanks 

Casing Head Gas 

Treater Burner 

RICE Enoine 

Truck Loadina 

Fuel Storage Tank 

Pneumatic Pump 

Pneumatic Controllers 

GlYCOl Dehvdrator 

ITotais (TPY) 

, I 

I I 

VOC 

1156.27 

29.25 

0.12 

7.93 

22.54 

N9!llillible 

N/A 

N/A 

N/A 

1818.12 

voc 

35.13 

29.25 

0.12 

7.93 

22.54 

Negligible 

N/A 

N/A 

N/A 

94.98 

Uncontrolled Potential to Emit 

Criteria Pollutants 

HAP PM H2S 

16.31 N/A N/A 

0.50 0.26 NA 

0.04 0.17 N/A 

1.19E-Ol 0.18 N/A 

0.21 N/A N/A 

N9!lliclible N/A N/A 

NlA N/A N/A 

N/A N/A N/A 

N/A NlA N/A 

, I 17.19 I I 36.93 , I 0.61 I I 0.61 II 0.61 II 75.18 I , 0.00 I I 

Allowable Potential to Emit 

Criteria PollutantsHOx PM PMl0 PM2.$ CO H2S 

3.34 0.16 0.16 0.16 18.19 N/A 

4.23 0.26 0.26 0.26 23.03 0.00 

2.25 0.17 0.17 0.17 1.89 N/A 

30.44 0.18 0.18 0.18 50.26 NlA 

NlA N/A NlA NlA NlA NlA 

N/A NlA N/A NlA N/A NlA 

N/A NlA NlA NlA N/A N/A 

NlA N/A NlA N/A N/A N/A 

N/A NlA N/A N/A N/A N/A 

I I 1.20 I I 40.27 I I 0.76 I I 0.78 I I 0.76 I I 93.37 I I 0.00 I I 

HCHO 

Negligible 

0.00 

Negligible 

0.12 

Negligible 

N/A 

Negligible 

Nellliclible 

Negligible 

0.16 I I 0.12 j 

S~ HCHO 

NIA N9!lliaible 

0.00 0.00 

0.01 Negligible 

1.45E-Ol 0.12 

N/A Negligible 

NlA NlA 

NIA Negligible 

N/A Negljgible 

N/A N9!lliglble 

0.16 I I 0.12 I 

IIDakota-3 E&P Company, LLC II 

Emission Summary 

Emissions of leed and lead compounds. fIuorid... sulfuric add mist. lotal reduced suIM. and reduced suIM compounds alii assumed to be negiligable for upstream oil & go. operation. on the FBIR. 
9590.15 

9906.54 

No 

FaclHIy: 

ptson-FBIR Pad 

~Hocl.tad Will.: 

II D;k~ta~E&P Co;pany, Lic II Olson 12.1HX, 12·1HC 12· 

1HY. 12·1HD. FBIR 13~HC. 

13·24HZ, 13·24HD 

Potential To Emit Actual 

Greenhouse Gasesb Greenhouse Gasesb 

co2 CH. N20 CO2 CH. N20 

OiVCondensale Tanks N/A 36.17 N/A 2467.71 0.00 0.05 

Casing Head Gas 4138.65 12.29 0.00 4138.65 12.29 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 loadino 0.07 0.47 NlA 0.07 0.47 N/A 

FuelStoraae Tank N/A N/A N/A N/A NlA N/A 

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

Pneumatic Controllers N/A N/A NfA N/A NlA N/A 

GlYCOl Dehydrator NfA NlA NIA NfA NfA NfA 

'Total. (!PY) I , 7108.96 I I 49.48 I I 0.12 I I 957U8 I I 13.31 I I 0.16 I 

GHG .....EmiHlona (tpyl: I 7158.56 I GHG ..... emissions (tpy): 

C02S (tpy): 8183.80 C02.(tpy): 

Appllcabkt to the Tailoring RuIs?: 

. 

• • • • 

HydrollUOl'OCllrtl"". (HFCs), _""""""",,no (PFes). al'd SuWur H__(SF6) eml ••1ons .no not."....ed from O&G prtJducllon __. 
• • • • 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY.12-1HD. FBIR 13-24HC.13-24HZ. 13-24HD 


Oakota-3 E&P Company, LLC 


Tanks 

Oil Production! 2705 BOPO 

Flare Gas Volume! 112,441 scI/day 

Lower Heating Value! 2395.38 Btu/scf 

Molecular Weight! 41.99 Ibflb-mole! 

VOG wt Fraction! 76.57% 

VOG Emission Facto1 0.649 tprtbopd ! 

HAPs: 

Benzene wt Fraction 0.0186% I 

Toluene wt Fraction 0.0132% I 

E-Benzene wt Fraction 0.0018% I 

Xylene wt Fraction 0.0109% 

n-Hexane wt Fraction 0.6143% 

2.2.4-Trimethylpentaner---::-:::=:::-_., 

wt Fraction! 0.0587% 

HAP Emission Factor! 0.006 tpy/bop<! ! 

G02 wt Fraction! 0.23% 

GH4 wt Fraction! 1.5K::J 

Conlrolled emissions are calculated based on a ~destruction efficiency 01 the vac gas. 

~"<"'fq~f)KJ,"Mjl4 4~1~~·~-":.-"""'1'_~~"'ii4~~ ,ffi llfJ 1$,,1 "'!l:lII .¢J~~~!!'/.!I'J,'ilI"'il~\iI'~_~~4ii",*, \\IlI'i\II# ", tit "1~ 
• • • • 

[ Dakota-3 E&P Company, LLC 


I Tanks 

Olson-FBIR Pad 


Associated Wells: 


Olson 12·1HX, 12-1HC 12·1HY. 12·1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 


CRITERIA POLLUTANT EMISSIONSa 

Uncontrolled VOCs (PTE): 

Using E&P Tanks Run: I 0.649 TPV VOCIBOPO I x 12704.87 BOPO x I 

ORE 

0% 11756•27 TPvl 

Controlled VOCs (Allowable): 

sing E&P Tanks Run: I 0.649 TPV VOC/BOPO I x I 2704.87 BOPO x I 

ORE 

98% 35.13 TPvl 

Uncontrolled HAPs (PTE): 

Using E&P Tanks Run: 

Benzene 4,685 scflhr 

E-Benzene 4,685 scflhr 

Toluene 4,685 scflhr 

n·Hexane 4,685 scflhr 

Xylene 4,685 scflhr 

2.2.4.Trlmethylpentane 4,685 scflhr 

x 

x 

x 

x 

x 

x 

1/379 scf/lb-mole 

1/379scfl1b-mole 

1/379 scfllb-mole 

1f379 scfflb·mole 

11379 scfflb-mole 

1/379 scfllb-mole 

x 

x 

x 

x 

x 

x 

41.99 

41.99 

41.99 

41.99 

41.99 

41.99 

lb11b·mol 

IbIIb·mol 

Ibllb-mol 

Ibllb-mol 

IbIIb·mol 

Ibllb-mol 

x 

x 

x 

x 

x 

x 

..gg 

~ 

~ 

~ 

~ 

~ 

~ 

x 

x 

x 

x 

x 

x 

ORE 

0% " 0.101blhr 

0",(, " 0.01 Iblhr 

0% " 0.071blhr 

0% = 3.191blhr 

0% = 0.061b1hr 

0% " 0.301blhr 

Uncontrolled TOTAL HAPS (TPV) 

.. 

= 

" 

.. 

.. 

" 

" I 

TPY 

0.42 

0.04 

0.30 

13.97 

0.25 

1.33 

16.31 

Controlled HAPs (Allowable): 

Benzene 4,685 scflhr 

E·Benzene 4685 scflhr 

Toluene 4,685 scflhr 

n·Hexane 4,685 scflhr 

Xylene 4,685 scflhr 

2.2.4.Trimetl1ylpenlane 4,685 scflhr 

x 

x 

x 

x 

x 

x 

1/379 scf/lb-mole 

1f379 scfl1b-mole 

1f379 scf/lb-mole 

11379 scfllb-mole 

11379 scfl1b·mole 

1/379 scfllb-moIe 

x 

x 

x 

x 

x 

x 

41.99 

41.99 

41.99 

41.99 

41.99 

41.99 

Ibllb-mol 

Ibllb-mol 

IbIIb·moI 

Ibllb-moI 

Ibllb-mol 

Ibllb-mol 

x 

x 

x 

x 

x 

x 

1 

~ 0•

02% 

..gg 

~ 

~ 

~ ~ 

x 

x 

x 

x 

x 

)( 

98% = 0.00 Iblhr 

98% " O.OOlblhr 

98% " O.OOlblhr 

98% " 0.061b1hr 

98% " 0.00 Iblhr 

98% " 0.01 Iblhr 

Controlled TOTAL HAPS (TPy) 

.. 

.. 

.. 

.. 

.. 

.. 

= I 

0.01 

0.00 

0.01 

0.28 

0.00 

0.03 I 

I 

0.33 I 

--­
• • • • 

Oakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1H~ 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 


Tanks 

Uncontrolled NOx: 

NOlI:' 0 scf/hr x , 2,395 Blulscf , 

0.00 Ib/hr 

x 

x 

1MMBlul1.000.000 Btu 

8760 hr!l!; x 

X I 0.068 IblMMBtu , 

I 1 10n/2000 Ib 

0.00 

0.00 

Ib/hr I 

TPYI 

NOx Created by Combustion (Actual) 

NOx:, 4,885 set/hr x I 2,395 Blulscf I 

0.76 IbIIlr 

x 

x 

1MMBlul1.000.000 Blu 

8760 hr/yr x 

X I 0.068 IbIMMBtu , 

, 1 t0n/2000 Ib 

0.76 

3.34 

Ib/hr I 

IPY , 

Uncontrolled PM: 

PM:' 0 scf/hr x I 7.6 1b/1.000.000 set 0.00 IbIIlr 

0.00 Ib/hr x 8760 hr!l!; x 1 lonI2000 Ib 0.00 TPY 

PM Created by Combustion (Actual) 

PM:l 4,885 set/hr x I 7.6 

0.04 

Ib/1.000.000 sef 

Ib/hr x 8760 hr/~ 

0.04 

x 

Ib/hr 

1 lonI2OOO Ib 0.16 TPY 

/t,MJIi) <1:; _______""",__""",,,,,,,,,...,.....,._____•____•_______________
• • • • 

Oakota-3 E&P Company, LLC 


Tanks 

Uncontrolled CO: 

co:! 0 scflhr x ! 2,395 

0.00 

Btulscfl 

Iblhr 

x 

x 

1MMBlu/1,OOO.OOO Btu 

8760hr~ x I 

x I 0.370 IbIMMBIu I 

1 tonl2000 Ib 

0.00 

0.00 

Iblhr I 

TPV I 

CO Created by Combustion (Actual) 

co:! 4,685 scflhr x I 2,395 

4.15 

Btu/sciI 

Iblhr 

x 

x 

1 MMBhM'1.000,OOO Btu 

8760 hr/l" _ I x I 

x I 0.370 IblMMBtu I 

1 tonl2000 Ib 

4.15 

I 18.19 

Iblhr I 

TPY I 

"NOx, S02. and CO emission factOB are from AP-42 Table 13.5-1 

(Emission Factors for Flare Operations) . 

Olson·FBIR Pad 


Associated Wells; 


Olson 12·1HX,12·1HC 12·1HY,12·1HD, FBIR 13-24HC, 13·24HZ, 13·24HD 

• • • • 

Dakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12·1HX. 12·1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 


Tanks 

REGULATED GREENHOUSE GAS EMISSIONSb 

Uncombusted CO2: 

C02:! 4,685 scflhr I x 111379 scfllb-mole I x 

1.20 

41.99 Ibllb-molel 

Iblhr x 

wt 

x ! 0.23% I 

8760 hr~ x I 

ORE x 0% 

1 tonl2OOO Ib 

1.20 

5.24 

Iblhr 

TPY 

C02 Created by Combustion (Actual) 

C02:! 4,685 scflhr x '120,000.0 Ibl1,OOO,OOO scf 

! 562.21 Iblhr I x 8760 hrfyr 

562.21 Iblhr ! 

x ! 1tonl2OO0lt'l I (2462.47 TPY :J 

..",__~~,l(>!____, d"'~"(f'<i?'!,,~,J>\E '~~,~~ UP,', oI~_,.WM"",_'_____________ 
• • • • 

Dakota-3 E&P Company, LLC 


[ ~n~ 

Uncontrolled CH4: 

wt ORE 

CH4:1 4,685 scflhr x 11/379 scfnb-mole 1 x 

8.26 

41.99 

Iblhr 

Ibllb-moIel 

x 

x 11.59% 1 

8760 hr!x!: x 1 

x 0% 

1 tonl2000 Ib 

8.26 

36.17 

Iblhr 

TPY 

Controlled CH4: (Actual) 

CH4:1 4,685 scf/hr x 111379 scfnb-mole 1 x 

0.17 

41.99 

Iblhr 

Ibllb-mole1 

x 

wt% 

x 11.59% 1 

8760 hrl~::J x 1 

ORE 

x 98% 

110012000 Ib 

0.17 

0.72 

Iblhr 

TPY 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 

• • • • 

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

(Emission Factors lor Natural Gas Combustion). 

Dakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX. 12-1HC 12-1HY.12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 


Tanks 

Uncontrolled N20: 

CH4:! 4.68l! scf/hr ! x 11/379 scfllb.mole ! x 

I 0.00 

I 41.99 1Mb-mole! 

Iblhr I x I 

wt% 

x 10.00% ! 

8760 hr/:t! I x I 

ORE x 1 0% 

1 tonl2000 Ib 

I 

I 

= 

= 

I 

I 

0.00 

0.00 

Ib/hr 

TPY 

! 

I 

N20 Created by Combustion: 

CH4:1 4,88l! scf/hr I x I 2.3 Ib/1,000,000 sef 

I 0.01 Ib/hr I x 

I = I 

I 8760 hrl:t! I 

0.01 Iblhr I 

x I 1 tonl2OOO Ib I = I 0.0l! TPY I 
• • • • 

Oakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 


Casing Head Gas 

Flare Gas VOlumel -7,832 sctlhr ](Takes into account the 10% of the lotal 

produced gas volume that is not being sold.) 

Lower Healing Valuerl--1~8:'::1-:4.":2:----:B:'!t-ul:-scf-:-"'"I 

Avg. Molecular Weight! 3Ul9 1Mb-mole I 

VOC wt fractionr 50.99% 

HAP wt fraeliol 1 0.72% 


0.06% 


0.01% 


0.01% 


0.68% 


0.05% 


Benzene wt fraction1 


E -Benzene wt fraetion1 


Toluene wt fraetio 1 


n-Hexane wt fraetio 1 


Xylene wt fractio 1 


2.2.4-Trimethylpentane...._-;;:-:;;;-;;;-_--, 

wt fractionl 0.00% 

C02 wt fraction! 0.77% -:::1 

CH4 wt fractionl- 21.42% 

Hours of Flaring Io~ 8760 hoursl),!" PTE:IL_ ________ 

Control Efflicie 98% ORE 
• • 

--------

Dakota-3 E&P Company, LLC 


• 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC.13-24HZ.13-24HD 


Casing Head Gas 

CRITERIA POLLUTANT EMISSIONS8 

Controlled VOCs (PTE): 

wt% Control % 

voe:1 7,832 scflhr x 11/379 scf/lb-mole x 

6.68 

1 31.6925 

IbIIlr 

1Mb-mole 1 

x 

x 

8760 hr/~ 

50.99%1 x 1 98% 1 

x 11 tonl2OO0 Ib 

6.68 

29.25 

Ib/hr 

TPY 

Controlled VOCs (Allowable): 

wt% ConllOl·~ 

voe:1 7,832 scflhr x 11/379 scfllb-mole x 

6.68 

1 31.6925 

IbIIlr 

1Mb-mole 1 

x 

x 

8760 hr~ 

50.99%1 x 1 98% 1 

x 11 tonl2OOO Ib 

6.68 

29.25 

Iblhr 

TPY 

• 


jItf,.,.QIll ~._!~#~~r!t!" 4¥,'~ l,I!'~~"if Wl\1~~"4~i'I'4iii"'''''1W" ","tI'M"~~'" 
• • • • 

Dakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX.12-1HC 12-1HY.12-1HD. FBIR 13-24HC.13-24HZ. 13-24HD 


Casing Head Gas 

Controlled HAPs (PTE): 

Using E&P Tanks Run: 

Benzene 7,832 scf/hr 

E-Benzene 7,832 scflhr 

Toluene 7,832 scflhr 

n-Hexane 7,832 scflhr 

Xyfene 7,832 scflhr 

2.2,4-Trimethyfpentane 7832 scf/hr 

Formaldehyde 7,832 scflhr 

x 

x 

x 

x 

x 

x 

11379 scfllb-mole 

11379 scfl1b-mole 

1/379 scfl1b-mole 

1/379 scf/lb-mole 

11379 scfl1b-mole 

11379 scfllb-mole 

7.50E"()2 IblMMscf 

0.12 

x 

x 

x 

x 

x 

x 

Iblhr 

31.6925 

31.6925 

31.6925 

31.6925 

31.6925 

31.6925 

x 

Ibllb-mol x 

IbII!)..mol x 

Ibllb-mol x 

Ibllb-mol x 

Ibllb-mol x 

Ibllb-mol x 

8760 hr~ 

wI% Control % 

0.06% x 98% 

0.01% x 98% 

0.07% x 98% 

0.68% x 98% 

0.05% x 98% 

0.00% x 98% 

x 11 lonl2OO0 Ib 

0.01 Iblhr ,. 

0.00 Iblhr 

0.01 Iblhr • 

0.09 Iblhr 

0.01 Iblhr 

0.00 Iblhr 

O.OOlblhr 

0.50 TPY 

TPY 

0.03 

0.01 

0.04 

0.39 

0.03 

0.00 

0.00 

Controlled HAPs (Allowable): 

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

Benzene 7,832 scflhr x 11379 scfllb-mole x 31.6925 Ibllb-mol x 0.06% x 98% 0.01 Ib/hr 0.03 

E-Benzene 7,832 scflhr x 1/379 scfllb-mole x 31.6925 Ibllb-mol x 0.01% x 98% 0.00 Iblhr 0.01 

Toluene 7,832 scf/hr x 1/379 scfllb-mole x 31.6925 IbII!)..mol x 0.07% x 98% 0.01 Iblhr 0.04 

n-Hexane 7,832 scflhr x 1/379 scfllb-mole x 31.6925 Ibllb-mol x 0.68% x 98% 0.09 Ib/hr 0.39 

Xyfene 7,832 scflhr x 1/379 scfllb-mole x 31.6925 Ibllb-mol x 0.05% x 98% 0.01 Iblhr 0.03 

2.2,4·Trimelhyfpenlane 7,832 scf/hr x 1/379 scfllb-mole x 31.6925 Ibllb-mol x 0.00% x 98% 0.00 Iblhr 0.00 

Formaldehyde 7,832 scflhr x 7.50E"()2 IblMMscf 

0.12 

x 

Iblhr 

1000000 

x 

scflMMscf 

8760 hrlyr x 11 lonl2OO0 Ib 

0.00 Iblhr 

I_O~TELJ 

0.00 
• • • • 

[ Dakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX.12-1HC 12-1HY.12-1HD. FBIR 13-24HC. 13-24HZ.13-24HD 


[ Casing Head Gas 

Uncontrolled NOx (PTE): 

NOx:! 7.832 setlhr x I 1,814 Btu/set 

0.911blhr 

x 

x 

1 Mmblul1.000.000 Btu 

8760 hr!l! x 

x 0.068 IblMMBtu I 

1 ton/2000 Ib 

0.91 

4.23 

Iblhr 

TPV 

NOx Created by Combustion (Actual): 

Nox:1 1,832 setlhr x I 1,814 Btu/set 

0.91Ib/hr 

x 

x 

1 Mmblul1.000.000 Btu 

8760 hr~ x 

x 0.068 IblMMBtu I 

1 ton/2000 Ib 

0.91 

4.23 

Iblhr 

TPV 

Controlled H2S (PTE): 

H2s:1 1.832 scflhr x 111379 scfnl>-mole x 

0.00 

1 31.6925 Ibnb-moie 1 x 

Iblhr x 8760 h~ 

wt"4 Control % 

0.00%1 x 1 98% 1 

x 11 tonf2000 Ib 

0.00 

0.00 

Iblhr 

TPV 

Controlled H2S (Actual): 

H~:I 1.832 setlhr x 11/379 scfllb·mole x 

0.00 

1 31.6925 Ib~b-mole 1 x 

Iblhr n I x n_8760 hrlyr nl 

wt% Control % 

0.00%1 x 1 98% 1 

x li!i:nI2OOO Ib 

0.00 

0.00 

Ib/hr 

TPV 
• • • • 

Dakota-3 E&P Company, LLC I 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX. 12-1HC 12-1HY.12-1HD. FBIR 13·24HC. 13-24HZ.13-24HD 


Casing Head Gas 

S02 Created by Combustion (PTE): 

5021 7.832 scflhr x 111379 sctnb-mole x 

0.00 

1 31.6925 

Iblhr 

Ibnb-mole I 

x 

x 

8760 hrlyr 

wt% Control % 

0.00%1 x I 98% I 

x [!1OO!2OO0 16­

0.00 

0.00 

lbih!] 

TPY 

S02 Created by Combustion (Actual): 

wt% Control % 

5021 - 7.832 scflhr:J x 11/379 scMb-mole x 

0.00 

1 31.6925 

Iblhr 

Ibnb-mole 1 

x 

x 

8760 hrlyr 

0.00""'1 x 1 98% I 

x 11 10nl2OOO Ib] 

0.00 

0.00 

Iblhr 

TPY 

CO Created by Combustion (PTE): 

cO:1 t;m- nSCflhr] x I 1.814 Btu/sef I x 1 Mmblu/1.000.000 Btu x 0.370 IblMMBlu I 5.26 Iblhr] 

5.26 Iblhi-::1 x 8760 hr/yr x 1 tonl2OOO Ib 23.03 TPY nJ 

CO Created by Combustion (Actual): 

cO:1 -7,832-------salhr:::J x 1 1.814 Btu/scf I 

5.26 Iblhr 

x 

x 

1 MmbIul1.000,OOO Btu 

8760 hrlyr -::1 x 

x O,370lblMMBtu I 

1 10nl2OOO Ib 

5.26 

23.03 

Iblhr J 

TPV:J 
• • • • 

Dakota-3 E&P Company, LLC 


Olson·FBIR Pad 


Associated Wells: 


Olson 12·1HX. 12·1HC 12·1HY. 12·1HD. FBIR 13·24HC. 13-24HZ. 13·24HD 


Casing Head Gas 

PM Created by Combustion (PTE): 

PM:I 7,832 scflhr x I 7.6 Ibf' ,000,000 scf 

O.06lb/hr x 8760 hr~ 

0.06 

x 

Iblhr 

, ton12000 Ib 0.26 TPY 

PM Created by Combustion (Actual): 

PM:I 7,832 scflhr x I 7.8 Ibt1 ,000,000 sef 

0.06 Iblhr x 8760 hr~ 

0.06 

x 

Iblhr 

1 ton/2000 Ib 0.28 TPY 

·NOx. S02. PM. & CO emission factors are from AP42 Table 13.5-1 and Table 1.4-2 

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

~~~~-~~""''''~'_ "x, ~O;, 4MI ~"'~"""~"l', "'!""~~*""'''''',,<))!I!!U4.,;'' 1\(_i'!"'1l"P~~~'~"~'>M'>#'''n , :""'!'I'~IMf _.,_____________• 
• • • • 

Oakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX. 12-1HC 12-1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13-24HD 


r 	 Casing Head Gas 

r-	 REGULATED GREENHOUSE GAS EMISSIONSb 

C02 (PTE): 


C02 Entrained In the Produced Gas: 


Control % 

C02:' .7;832 ·_-seJ?hi:J x !11379 sctnb-mole x 131.6925 Ibnb-mole 1 x 0.77%1 x I 98% I 5.04 Ibfhr 1 

5.04 Ibfhr x 8760 hr!yr x 1110nl2OOO fb :J 22.07 TPYl 

C02 Created by Combustion: 

C02:! 7,832 scflhr x 1120,000.0 Jbl1.000.000 scf 	 I 939.8616Jhi 

939.86 Iblhr 	 x 8760 hr!yr :;J x ,-110012000 It:i 4116.58 TPY ] 

Total C02 Emitted (PTE):I 4138.65 TPY 
• • • • 

Dakota-3 E&P Company, LLC 


C02 (Actual): 


C02 Entrained In the Produced Gas: 


wt% Control % 

C02:! 7.832Sdlhr x [i7379Sdh6:moD x ! 31.692~rriOie I x 0.77%1 x 1 98% 1 r 5.04 Iblhr 

004 Ib/hr x 8760 hriyr x (!1on/2000 Ib 22.07 TPY --I 

C02 Created by Combustion: 

C02:! 7,832 scflhr _ul x 1120.000.0 1f)11.000.000scf 939.86 Ib/hr 


r:::J39-86 Ib/hr x 8760 hriyr uJ x 1----rtOnI2OO0 If) 411&.58 fPY 


Total C02 Emitted (Allowable):! 4138.65 TPV 


Olson·FBIR Pad 


Associated Wells: 


Olson 12·1HX. 12·1HC 12·1HY. 12-1HD. FBIR 13-24HC. 13-24HZ. 13·24HD 


Casing Head Gas 

Controlled CH4 (PTE): 

CH4:1 7.832 scflhr x 111379 scf/lb-mole x 

2.81 

1 31.6925 

Ib/hr 

Ib/lb-mole I 

x 

x 

8760 hriyr 

wt% Control % 

21.42%1 x I 98% I 

x 11 ton12oo0 Ib 

2.81 

12.29 

Ib/hr 

TPY 

Controlled CH4 (Actual): 

CH4:1 7.832 scflhr x 111379 scfl1b-mole x 

2.81 

I 31.6925 

Ib/hr 

Ibl1b-mole I 

x 

x 

8760 hr~ 

wt% Control % 

21.42%1 x 1 98% I 

x ,1 tonl2Ooo Ib 

2.81 

12.29 

Ib/hr 

TPY 
• • • • 

CO Oakota-3 E&P Company, LLC 


I 0 Casing Head Gas 

N20 Created by Combustion (PTE): 

N20:! 7,832 scflhr x ! 2.2 Ib/1.000.000 scf 

I 1.72E.o2 Iblhr x 8760 hr!f 

!1.72E.o2 Iblhr 

x 1 tonl2OOO Ib I 4.31E.o3 TPY 

N20 Created by Combustion (Actual): 

.­

N20:! 7,832 scflhr x I 2.2 Ib/1,OOO.OOO scf 

[j:fiE.o2 lbihr__l x I _ 8760hr~__ 

I 1.72E.o2 Iblhr 

x L 1 lonl2OO0 Ib _ ! 4.31E.o3 TPY 

Olson-FBIR Pad 


Assodated Wells: 


Olson 12·1HX. 12-1HC 12·1HY. 12·1HD. FBIR 13·24HC. 13-24HZ. 13-24HD 


he02 and N20 emission factors are from AP-42 Table 1.4-2 

(Emission Factors for Natural Gas Combustion) . 
• • • • 

Dakota-3 E&P Company, LLC I 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 


Heater Treater Burnera 

Burner Rating I 5,250,000 Btulhr !Thls burner rating reflects the combined size of all of the proposed heater treater burners at the facility. 

NOll:[ 0.10 IblMMBlu x 5.25 MMBlulhr I :: 0.515 Iblhr 

CO:S147 Iblhr x 8.760 hr!yr x '1 ton 12000 Ib , = 2.254 TPY 

co:, 0:08 IblMMB!i[l x 5.25 MMBtulhr , 0.432 Iblhr 

0.43 Iblhr x 8.760 hr/yr )( I 1 ton 12000 Ib , 1.894 TPY 

s02:15.88E-04 IblMMBIu x 5.25 MMBtUlhi', CO.OO3 Iblhr 

13.09E-03 Ib/hr::J x 8.760 hr!yr x I 1 ton 12000 Ib I" 0.014 TPY 

PM:, 0.01 16IMMBtu x 5.25 MMBtulhr I ( 0.039 Iblhr 

~lblhr=:J x 8,760 hrlyr x , 1 Ion 12000 Ib I r 0.171 TPY 
• • • • 

Oakota-3 E&P Company, LLC 


Heater Treater Burnera 

voc;, 0.01 IblMMBtu )( 5.25 MMBiU7!ifl i.f.lI28l6lhr:J 

0.03 Iblhr )( 8,760 hriyr )( I 1ton f 2000 Ib I r 0.124 TPY::J 

HAP;I O.0021b/MMBlu:J )( 5.25 MMBtufhr I 0.010 Ibfhr 

19.7~~-53 Iblhr )( ~,760 hr~ )( 11 tonf20OOlbl = 0.043 TPY 

c021117.647 IbfMMBtu )( 5.25 MMBtufhr I 617.647 Ibfhr 

rn.18E+02 Ibfhr )( 8,760 hrlyr )( Utonf2000lbj I 2,705.294 TPY 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY. 12-1HD, FBIR 13-24HC, 13-24HZ. 13-24HD 

• • • • 

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

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

CH4:1 0.007 Ib/MMBtu 

13.47E-02 Iblhr 

Oakota-3 E&P Compan~, LLC 

• 

Olson-FBIR Pad 

Associated Wells: 

Olson 12-1HX, 12-1HC 12-1HY, 12-1HO, FBIR 13-24HC, 13-24HZ, 13-24HO 

Heater Treater Burnera 

x 5.25 MMBtulhr I 

x 8,760 hrlyr I x 11 lon/2000lbl 

= 0.035 Iblhr 

0.152 TPY 

H20:1 0.001 IblMMBtu x CS:25 MMBtWfif] 0.007 Iblhr J 

16~E:.o3 Iblhf :::;J x 8,760 hr'i x 11 Ion 1200016 I r::::p:!3O U rpv

2.25 NOxTPY 

1.89 COTPY 

o.or--S52-TPY 

0.17 -PMTPY 

0.12 VOC TPY 'I 

C 0.04 HAP TPY ul 

2705.29 C02 TPY 

0.15 CH4 TPY 

~J'I!.";.rRIO\."lm~~~"!I"~•. *6 A 4 ..i(IIIMil"~ft""''''______ 

0.03 N20TPY 
• • • • 

Oakota-3 E&P Com LLC 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 


Truck Loadout Emission Calculation II 

Saturation Vapor Molecular Temp + Load Loss 

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

12.46 I x I 0.60 I x I 2.30 I x I 41.99 I I I 510.00 I = I 1.42 

LL Truck Load Load Time Total Gas 

Ibl1 ,000 gal Rate bbVhr hrs gallbbl Emissions Ib/hr 

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

LL Annual Emissions Uncontrolled 

Ib/1.000 gal bbll~ ~a"bbl Ib/ton TPY C3+VOCt~ 

1.42 I x I 9872n.88 I x I 42.00 I I I 2000.00 I =I 29.44 I I 22.54 ! 

vae 

Emissions 


Uncontrolled Control % TPY 


22.54 I I 0% I I 1.00 I L22.54] 

=-== 
• • • • 

=­

LL Annual Emissions Uncontrolled 

Ib/1,000 gal bbl/yr aallbbl Iblton TPY HAPstov 

1.42 I x I 987277.88 I x I 42.00 I I I 2000.00 I =I 29.44 I I 0.21 

HAPs 


Emissions 


Uncontrolled Control % TPY 


0.21 I 0% 1.00 0.21 I 1 I 1 I 1 

LL Annual Emissions Uncontrolled 

Ib/1 ,000 gal bbl/yr gaVbbl Iblton TPY C02tov 

1.42 I x I 987277.881 x I 42.00 1 I I 2000.00 1 =I 29.44 I I 0.07 

CO2 


Emissions 


Uncontrolled Control % TPY 


0.07 I 0% 1.00 0.07 I 1 I 1 I 1

LL Annual Emissions Uncontrolled 

Ib/1,OOO lal bbVyr aallbbl Iblton TPY CH4tpy 

1.42 I x I 987277.88 I x I 42.00 1 I I 2000.00 1 =1 29.44 I I 0.47 

CH4 


Emissions 


Uncontrolled Control % TPY 


0.47 I I 0% I I 1.00 I I 0.47 I 
Oakota-3 E&P Company, LLC I 

II RICE Input Data ! 

Combined Diesel Engines Description 

Hours of Operation 8760 IlEngint lI_umed to operata 8,788 houri per year. 

Maximum HP Rating 1925 

NOxglhp-hr 1.49 E +00 IMinufacturer GUlrantee (40 CFR 63 Subpart. requlrament1l), _ Attachment F 

CO a/hp..hr 2.61 E+OO IMInUtacturer GUlrlntee (40 CFR s3 Subpart 1I11equ1rementa1- Attachment F 

S02gJhp..hr 4.52E-06 IAfI.42 Tible 303·1 

PM !l/hp..hr 4.85E-06 1Af'.42 Tible 3.3-1 

lVoc a/hp..hr 1.42E-01 ....nuflcturer Guarentee (40 CFR 63 Subpart III requlmnenta), _ Attachment F 

HAP glbh-hr 1.02E·06 IlAP-42 Table 303·1 

C02 glbh-hr 2.54E-03 1IAf'.42 Table 3.3-1 

CH4 glbh-hr 2.10E-02 140 CFR98 Subp.rtC, Table Co2 

N20 !l/hp-hr 4.20E-03 1140 CFR 118 Subp.rt C, Tlble Co2 

Recycle Pump Description 

Hours of Operation 8760 IlEnginel, _umed to operata 8,780 hOUri per year. 

Maximum HP Rating 56 IlManufacturer's maximum hp I'IlIng. 

NOxg/hp-hr 4.99E+OO IAfI.42Tlble3.3-1 

CO !l/hp..hr 3.1SE+OO 11Af'.42 Tible 3.3-1 

S02g/hp..hr 2.S8E·01 1IAf'.42 Tlble 3.3-1 

PM glhp..hr 3.27E-01 1Af'.42 Tible 3.3-1 

lVoc g/hp-hr 9.80E+OO 1Af'.42 Tible 3.3-1 

HAP glhp-hr 2.20E-01 IAfI.42 Tlble 3.3-1 

C02Q1bh-hr 4.90E+02 0Af'.42 Tible 3.3-1 

CH4 alhp..hr 2.10E-02 I4OCFRIIBSubplrlC, Table Co2 

N20 glhp-hr 4.20E-03 1140 CFRIIBSubpert C, Table Co2 

• • • • 
• • • • 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 


Oakota-3 E&P Company, LLC 


Reciprocating Engine Emissions 

ENGINE #1 

1925:1 MAX HP 

.t!Q& I 1.49E+GlfijlHP-HRI x 1925 HP x 11Ib/453.&arams 6.33E+OO Iblhr x 8780 hr!f; x [!ion/2000lbl =12.77E+01 NOxTPY I 

~ I 2.1I1E+OO g/Hp-HRI x 1925 HP x 11 Ib' 453.6 ~rams 1.11E+01 Iblhr x 8780 hr~ x 1 ton' 2000lbl 4.8&E+01 co TPY 

~ 4.52E-OII g/Hp~HR] x 1925 HP x 11 Ib 1453.& ~rams = 1.92E-05 Iblhr x 8780 hr~ x 1 ton 12000lb 1 = 8.40E-OS 502 TPY 

eM.;. 4.85E-OII gniP-HR I )( 1925 HP )( 11 Ib 1453.& ~rams • 2.CI6E-05 Iblhr )( 8780 r~ x 1ton 12000lbl = 9.02E-05 PM TPY 

~ U2E-01 g!HP-HRI x 1925 HP x 11 Ib 1453.6 ~rams 1I.02E-01 Iblhr x 8780 r~ x 1 ton 12000lb 1 2.ME+OO VOC TPV 

!:t!fi 1.02E-OII g!HP-HR I x 1925 HP x 11 Ib 1453'&l!rams ...33E-OII Iblhr x 8780 hr~ x 1 ton 12000Ibi 1.90E-OS HCHO TPY 

QQ.Z;. 2.ME-03 gniP-HRI x 1925IHP x 11 Ib 1453.&arams 1.08E-02 Iblhr x 8780 hr~ x 1 ton I 2000lbI 4.71E-02 CO2 

CH4: I 2.10~g?HP:HR] x 1925 HP )( 11 Ib 1453.6 ~rams 8.91E-02 Ib/hr x 8780 hr!l!; x 1 ton/2000lbl 3.90E-01 CH4 

H2Q: I ".20E:cJa !!!AP:ARI )( 11925 HP x 11 Ib 1453.& grams 1.76E-02 Iblhr )( 8780 hrlyr x 1 ton 12000lbl = 7.81E-02 N20 

'* $$ QIIII_ ; .,II"'~- j " ,"EJ'~~,"'II"""'" ;;p. , ,W 1fI;;;1i 4 atl~.IIjI{<ii:;;; ,t, wus"!,, h"Iki\4ii,l4f ,<!" ",II1II) 4->4 l!,;lth~ Fii,¥h~ s 
• • • • 

Oakota-3 E&P Company, LLC 


Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13-24HD 


Reciprocating Engine Emissions 

ENGINE #2 

56 'MAXHP 

NOx: I 4.99E+OO ijJHP:AR] x ! . se-Ap] x 11 Ib I 453.6 grams I x 0.62 Iblhr x 8760 hr~ x 1 ton 12000lb' 2.70E+00 NOx TPY 

2Q.;, I 3.1eE+00ij7Hp:A!f) x 56 HP x 11 Ib 1453.6srams I x 0.39 Iblhr x 8760 hr~ x 1 ton 12000lbI = 1.71E+00 CO TPY 

I U8E..o1 glHP-HRI x 56 HP x l' Ib I 453.6 Srams I 3.31E..o2 Iblhr x 8760 h~ x 1 ton 12000lbI 1.45E-01 802 TPY " 

f.Mi I 3.27E..o1 glHP-HRI x 56 HP , x l' Ib 1453.6I1rams I 4.04E..o2 Iblhr x 8760 hr~ x 1 ton 12000tbi 1.77E-01 PM TPY 

,9.80E+00 giHP-HR! x 56 HP x 11 Ib I 453.6I1rams x 1.21 Iblhr x 8760 hr~ x 1 ton 12000lbl 5.30E+00 vee TPY 

HAP: I 2;:zoE-Ofg?HNi]l x 56 HP x 11 Ib I 453.6I1rams 0.03 Iblhr x 8760 hr~ x 1 ton 12000tbI 1.19E-01 HAP TPY 

I 4.90E+02 giHPfiR] x 56 HP x 11 Ib I 453.6srams 6.05E+01 Iblhr x 8760 hr~ x 1 ton 12000lbI 2.65E+02 C02 TPY 

CH4: I 2.10E..o2 gIHP-HR! x 56 HP x 11 Ib 1453.6I1rams 2.59E..o3 Iblhr x 8760 hr~ x 1 ton 12000tbI 1.14E-02 CH4 TPY 

N20: ! 4.20E..o3 glHP-HRI x 56 HP x j1lb /453.6 grams 5.19E-04 Iblhr x 8760 hrlyr x 1 ton 12000lbI 2.27E-03 N20M:] 
• • • • 

Olson-FBIR Pad 


Associated Wells: 


Olson 12-1HX, 12-1HC 12-1HY, 12-1HD, FBIR 13-24HC, 13-24HZ, 13·24HD 


Dakota-3 E&P Company, LLC 


Reciprocating Engine Emissions 

TOTALS 

3.04E+01 NOx TPY 

5.03E+01 co TPY 

1.45E'()1 502 TPV 

1.77E'()1 PM TPY 

7.t3E+OO VOC TPY 

1.1tE'()1 HAP TPY 

2.GSE+02 CO2 TPY 

4.02E·01 CH4 TPY 

8.03E'()2 N20 TPY 
• 


ATTACHMENT C: FLASHING EMISSIONS CALCULATIONS 

• E&P Tanks Emission Summary 

• E&P Tanks Linear Relationship (Emission Factor) 

• 

• 

Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


van Hook Field 1000 BOPD wt% 

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

* project Setup Information * 

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

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

IR well work\E&p Tanks\van Hook Field 1000 BOPD.ept Flowsheet Selection oil Tank with Separator calculation Method RVP Distillation 

control Efficiency 100.0% 

Known Separator Stream Low Pressure oil 

Entering Air Composition No 

Filed Name Van Hook 


well Name pennington 16-1SH and Van Hook 16-14H Averages
 Permit Number oakota-3 E&P company, LLC 

Date 2010.09.24 

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

* Data Input * 

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

Separator Pressure 52.00[psig] Sep~rator Temperature 90.00[F] Amblent Pressure 13.70[psia] Ambient Temperature SO.OO[F] C10+ SG 0.7970 

C10+ MW 233.494 

LOW Pressure oil ---------------------------------------------------------------------­ NO. component wt % . 

1 H2S 0.0027 

2 02 0.0000 

3 C02 0.0038 

4 N2 0.0008 

5 C1 0.0261 

6 c2 0.3417 

7 c3 1.3723 

8 i-c4 0.3662 

9 n-c4 1. 6928 

10 i-CS 0.6858 

11 n-C5 1.2496 

12 c6 1.4712 

13 C7 7.9550 

14 C8 19.2940 

15 C9 13.4810 

16 C10+ 49.4241 

17 Benzene 0.0470 

18 Toluene 0.1281 

19 E-Benzene 0.0586 

20 xyl enes 0.3912 

21 n-c6 1.5420 

22 224Trimethylp 0.4660 

• sales oil ----------------------------------------------------------------------------­ production Rate 1000 [bbl/day] Days of Annual operation 365 [days/year] API Gravi ty 41.5 

Reid vapor Pressure 6.20[psia] 

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

* Calculation Results * 

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

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

[ton/yr] [1 b/hr] 

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

Total HAPs 6.040 1.379 

Total HC 836.657 191.018 


vocs, c2+ 823.270 187.961 


VOCs, c3+ 649.305 148.243 


Page 1 

• 

• 

Van Hook F;eld 1000 SOPO wt%~ 

uncontrolled Recovery Info. 

vapor 41.5700 [MSCFO] 

HC vapor 41.3600 [MSCFO] 

GOR 41.57 [sCF/bbl] 

Emission Composition --------­ NO 	 Component uncontrolled uncontrolled 

[ton/yr] [lb/hr]

1 H2s 1.343 0.307 

2 02 0.000 0.000 

3 co2 1.941 0.443 

4 N2 0.412 0.094 

5 C1 13.387 3.056 

6 c2 173.965 39.718 

7 c3 448.169 102.322 

8 i-C4 34.294 7.830 

9 n-C4 102.418 23.383 

10 ;-c5 13.956 3.186 

11 n-C5 18.394 4.200 

12 c6 6.270 1.432 

13 

14 c8 

C7 10.476 

7.517 1.716 

2.392 •

15 C9 1.774 0.405 

16 c10+ 0.002 0.000 

17 Benzene 0.156 0.036 

18 Toluene 0.111 0.025 

19 E-Benzene 0.016 0.004 

20 xylene:s 0.090 0.021 

21 n-C6 5.168 1.180 

22 	 224Trimethylp 0.493 0.113 

Total 840.352 191.861 

Stream Data --------------------------------------------------------------------------­ NO. 	 Component MW LP oil Flash oil sale oil Flash Gas W&S Gas Total Emissions ~% ~% ~% ~% ~% ~% 

1 H2s 34.80 0.0027 0.0024 0.0001 0.1791 0.1609 0.1631 


2 02 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 


3 co2 44.01 0.0038 0.0026 0.0000 0.5796 0.1818 0.2307 


4 N2 28.01 0.0008 0.0001 0.0000 0.3282 0.0099 0.0490 


5 C1 16.04 0.0261 0.0112 0.0000 7.4009 0.7777 1.5911 


6 c2 30.07 0.3417 0.2811 0.0024 30.3262 19.3302 20.6806 


7 c3 44.10 1.3723 1.3000 0.5065 37.1767 55.5360 53.2811 

8 i-c4 58.12 0.3662 0.3594 0.3044 3.7640 4.1203 4.0766 

9 n-c4 58.12 1.6928 1.6719 1.5180 12.0581 12.1907 12.1744 

10 i-C5 72.15 0.6858 0.6836 0.6696 1.7610 1.6447 1.6590 

11 n-C5 72.15 1.2496 1.2474 1.2340 2.3296 2.1666 2.1866 

12 C6 86.16 1.4712 1.4725 1.4830 0.8134 0.7577 0.7645 

13 C7 100.20 7.9550 7.9683 8.0662 1.3546 1.2768 1.2865 

14 C8 114.23 19.2940 19.3310 19.6004 0.9553 0.9145 0.9195 

15 c9 128.28 13.4810 13.5078 13.7022 0.2134 0.2208 0.2201 

16 C10+ 233.49 49.4241 49.5238 50.2483 0.0000 0.0000 0.0000 

17 Benzene 78.11 0.0470 0.0471 0.0475 0.0197 0.0184 0.0186 

18 Toluene 92.13 0.1281 0.1283 0.1300 0.0137 0.0131 0.0132 

19 E-Benzene 106.17 0.0586 0.0587 0.0596 0.0020 0.0020 0.0018 It 

20 xylenes 106.17 0.3912 0.3920 0.3976 0.0109 0.0106 0.0109 

21 n-c6 86.18 1.5420 1.5438 1.5575 0.6517 0.6091 0.6143 

22 224Trimethylp 114.24 0.4660 0.4668 0.4728 0.0617 0.0581 0.0587 

MW 137.41 138.18 142.90 36.81 42.83 41.99 


Stream Mole Ratio 1.0000 0.9924 0.9456 0.0076 0.0468 0.0544 


Heating value [BTU/SCF] 2105.43 2442.60 2395.38 


Gas Gravity [Gas/Air] 1. 27 1.48 1.45 


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


page 2---------------------------------------------------------------- E&P TANK 

RVP @ 100F [psia] 15.49 13.82 6.27 


Spec. Gravity @100F 0.673 0.674 0.677 


• 

Page 2 
• 


Oil Storage Tank Flashing Emissions Calculation Methodology 

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

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

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

of the oil with the given inputs listed below. 

Inputs: 

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

Separator: 52 pSig, 90 degF 

Flash Valve: 13.7 pSia, 50 degF 

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

• 

Outputs: 

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

Emission (tons/yr) 

Total HC 0 41.83255 83.6651 250.9953 836.651 

VOCs, C3+ 0 32.46485 64.9297 194.7891 649.297 

Total HAPs 0 0.302 0.604 1.812 6.04 

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

HAP Emission Factor: 0.00604 tpy/BOPD 

Tank Emissions by Production Rate 

700 


600 


500 
 ... ......-Total HAPs 

CIS 400 _VOCs,C3+

~ 300 --Linear (Total HAPs) 

c 200 --Linear (VOCs, C3+) S 100 

o 

-100 

bbl/day 

• 


• 

• 

ATTACHMENT D: 	 REPRESENTATIVE LOW PRESSURE OIL 

ANALYTICAL DATA 

• 


• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 


Laboratory • Gas Measurement 

Emissions Testing • Sample Collection 

A2LA Ac~lted • /"iCtAl" Accredited • CPA Certlficd 

29 Country Aerts Rd. HI...,rton. "'''' 82501 • TolIl'fte. C8fi6) 985-0866 • £·....11' Info(iH'.eclslon·t..b".eolll • Online, www.P'n:c:blon·t.......UIIII 

EXTENDED HYDROCARBON (GLYCALC) LIQUID STUDY 


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


Lab Number ............... . CR-10330 


Date Sampled ............. . 7-15-2010 


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


CR-S 

7-23-2010 

80F 

MONTRAIL 

yz PISTON 

• 


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


Sample Pressure ......... 


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


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


MONTANA. 

28 PSIG 

SPOT 

GPA-2286 

Components Mole%. Weight 0/0 

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


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


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


• 


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


2,2,4-Trimethylpentane ... 


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


0.009 0.002 

0.000 0.000 

0.010 0.003 

0.003 0.001 

0.184 0.021 

1.152 0.241 

3.568 1.096 

0.778 0.315 

3.694 1.496 

1.242 0.624 

2.270 1.141 

2.276 1.367 

10.418 7.274 

24.125 19.203 

16.003 14.302 

30.668 50.576 

0.090 0.049 

0.183 0.117 

0.047 0.035 

0.455 0.337 

2.304 1.384 

0.521 0.415 

100.000 100.000 

Study Number•......... 


Date Tested ............ . 


Sample Temperature .... 

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

Sampling Method........ 

Liq. Vol. % 

0.002 

0.000 

0.003 

0.001 

0.051 

0.501 

1.600 

0.414 

1.896 

0.739 

1.339 

1.523 

7.823 

20.117 

14.658 

46.892 

0.041 

0.100 

0.030 

0.288 

1.542 

0.441 

100.000 

• 


I 
• 

ADDITIONAL BETX DATA 

Components Mole % Weight °/0 Liq. Vol. % 

2-Methylpentane 1.293 0.777 0.866 

3-Methylpentane 0.983 0.590 0.658 

n-Hexane 2.304 1.384 1.542 

2,2,4-Trimethylpentane 0.521 0.415 0.441 

Benzene 0.090 0.049 0.041 

Toluene 0.183 0.117 0.100 

Ethylbenzene 0.047 0.035 0.030 

m-Xylene 0.056 0.041 0.035 

p-Xylene 0.291 0.216 0.184 

o-Xylene 0.108 0.080 0.068 • 

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


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


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


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


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


TRUE VAPOR PRESSURE AT 100 F. PSIA, calculated ................................................ 28.847 


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


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


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


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


:\( n ATlff... AU (>\L( U.HI( )!\:~. PERFORillED L'SlN(' PHYSIC,] C(l~S'L\NrS FROM GPA .:2}45 09. THE 'f ABLI·.5 

Ul PHYSICAl CO~ST:\"TS FOR H)1)ROC>\RBONS .AND OTHI::R C()~IPUl :;";D~· or INTEREST 

.. 

1'0 THr. "IyftR AI C:\S INDl'STRY 

• 
• 


EXTENDED HYDROCARBON LIQUID STUDIES 

CERTIF1CATE ()1- ANALYSIS 

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


Lab Number............. CR-I0330 Study Number............ CR-5B 


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


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

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

• 

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

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

1-QUART 

Test Method.............. VARIOUS 	 Sample Container •...•.•. BOTfLE 


TEST PERFORMED 

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


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


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


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


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


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


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


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


• 

RESULTS, 

41.2 

0.8193 

4.6 PSIG 

1,562.18 	 PPMW 

N/A 

N/A 

N/A 

N/A 

NOTATION: ALL TESTING PROVIDED ABOVE WAS PERFORMED IN ACCORDA.:'ICE TO METHODOLOG\ 

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

• 

ubo".IOf) l'IusulCJtltnl 

PRE~ f,mlniDru TbUng • 5Itmpk CoUecJlon

•

.A SIS 

Chromatogram VanHook 16-14 C:\GCso!ution\DRO\DRO Data\08-2010\08-01-2010\VanHook 16-14.gcd - Channell 

o 100000 150000 200000 250000 

Intensity 

2.666/ 

---------------4.069/ 

"-------------5.608/Decane (CIO) ---------5,947/ 

"=".,---------------7,082/ 

•

========:mm-:r------- 8.451/ 


"""'::-:-------------9,724 / 


....:.:::.;:..;:..:...--------10,912/ 


-----------12.031/ 


-------13,087/ 


__hH.tfH---14.089/ 


1-+----15.948/o-terphenyl 

• 

:i' 

• 

3 
• 


Laboratory • Gas Measurement 

Emissions Testing • Sample Collection 

A2l..A Accredited • 1"t£l..Af' Accredited • EPA Certifled 

29 Counlry ik..... Rd. RI"",rton. lollY 82501 • Toll Fre",: (866) 98~..0866 • E-mail: Info@p.",clslon-Labs.c:om • Onlln",: wwv.Predslon·La.....c:om 

EXTENDED HYDROCARBON (GLYCALC) UQUID STUDY 

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


lab Number ............... . CR-10330 Study Number ............ .. CR-4 


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


• 

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

Sample location .......... MONTANA. 


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


Type Sample ............... SPOT County ........................ MONTRAll 


Test method ................ GPA-2286 Sampling Method........ YZPISTON 


Components Mole % 

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


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


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


• 


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


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


2,2,4-T rimethyl pentane ... 


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


0.012 

0.000 

0.013 

0.004 

0.270 

2.018 

5.113 

0.980 

4.432 

1.409 

2.562 

2.488 

11.732 

22.998 

13.316 

28.387 

0.078 

0.204 

0.107 

0.573 

2.688 

0.616 

100.000 

Weight % 

0.003 

0.000 

0.004 

0.001 

0.032 

0.448 

1.663 

0.420 

1.900 

0.750 

1.364 

1.582 

8.673 

19.381 

12.600 

48.236 

0.045 

0.139 

0.084 

0.449 

1.709 

0.519 

100.000 

Liq. Vol. % 

0.003 

0.000 

0.004 

0.001 

0.078 

0.920 

2.400 

0.546 

2.381 

0.878 

1.582 

1.743 

9.222 

20.074 

12.767 

44.369 

0.037 

0.116 

0.070 

0.379 

1.883 

0.545 

100.000 

• 

• 

• 

• 

• 

ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

2-Methylpentane 1.398 0.889 0.979 

3-Methylpentane 1.090 0.693 0.764 

n-Hexane 2.688 1.709 1.883 

2.2,4-Trimethylpentane 0.616 0.519 0.545 

Benzene 0.078 0.045 0.037 

Toluene 0.204 0.139 0.116 

Ethylbenzene 0.107 0.084 0.070 

m-Xylene 0.067 0.053 0.045 

p-Xylene 0.386 0.302 0.255 

o-Xylene 0.120 0.094 0.079 

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


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


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


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


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


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


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


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


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


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


'(IT\TION \U C\LU, I '\T\()"~ PFRl'llRMED l'SI:\l, PHYSIC>,l COt--ST-\l\:TS FRO?\ll;PA 214:,·(19, THF L\BI.E~ 

OF PHYSIC\I U )l\:Sl \l\:T5 F(lR HYDRO( >,RB(l!\S \1\D OTHER U J;\jPUl'NDS (lll:\TEREST 

)'0 THL l\:.-\TlR-\1 (,,\5INDlSTR) 

61.9 

0.7318 

0.7956 

135.548 

230.327 

43.649 

283.928 

19.480 

121815.044 

6.102 
• 


EXTENDED HYDROCARBON LIQUID STUDIES 

CERTIFICATE ()F :\\.lALYSIS 

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

Lab Number............. CR-10330 Study Number............ CR-4B 


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


Sample Identification ................ PENNINGTON 16,·15 H CRUDE OIL 


• 

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

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

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

1-QUART 

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


TEST PERFORMED 

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


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


REID VAPOR PRESSURE (ASTM D.323), PSIGAT 100 F.............. 


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


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


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


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


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


• 

RESULTS 

41.8 

0.8165 

7.8 PSIG 

1,435.60 	 PPMW 

N/A 

N/A 

N/A 

N/A 

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

OL'TLlNED BY THE AMERICA-'\! SOCIETY FOR TESTING AND MATERIALS (ASTM), 

• 

Report(Report Editor) 

Chromatogram Pennington 16-15H C:\GCsolution\DRO\DRO Oata\08-201 0\08-01-201 O\Pennington 16-15H.gcd - Channell 

o 50000 100000 150000 200000 

Labor.olory , Ga!o JiIIusuremt.nt 

PRE~ £.mlnlona Tblmg • !leIl1pl«o CoUe<.lkin

•

.A :r SIS 

• 

• 

• 

Intensity 

3 

:i' 

==;;;;.J..:iJS",-__3.637 1 

""::::===~=====~;;;1------5.6091 DecaDe (CIO) ,... 5.9491 

=-------------7.0831 

=====8.6'33r-------8.4521 

~---------- 9.7241 

,;;,,;;,;--------10.9121 

--------12.0301 

-----­13.0871 

---nt"'nl'l"'t- 14.0901 

15.948 Io-tetphenyl 

30.01­

2.6671 
• 


ATTACHMENT E: REPRESENTATIVE GAS ANALYSIS 


• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• • • • 

. LL4,r· 

methyl Hutlnll SpKIfIc AVI. 

coz Nltroa"n HilS Cl Q 0 1,(;4 n>C4 J.C5 n.(;S ca. 8enHn" ToIuen" E·8enr_ Xy"'n" "-Hexane pentane Va-Iu. Grmty MGktcufat 

welln.me iWt"l (Wt%) 1M"""', iWt"l (WI'" iWt", iWt"l (Wt%) iWt", (Wt%, CSIWt%) C1(Wt%, iWt"l (Wt%, (Wt%) (Wt%) iWt", (Wt"} iWt", IBtu/scI) Calculated Weltht 

44.010 28.013 34.081 16.043 30.069 44.096 58.122 58.122 72.149 72.149 86.1SO 101.21 114.23 78.112 92.140 106.170 106.160 86.ISO 114.230 

Pennington 16-15 1.003 I 4.652 I 0.000 I 32.081 J 23.021 I 22.839 J 2.571 I 7.695 1.238 I 1.722 1.nO 0.500 0.306 0.056 0.089 0.012 0.055 0.389 0 1511.141 0.927 26.848 

MaryASmitl> 0.536 I 0.410 I 0.000 I 10.763 I 23.813 I 33.276 I 4.811 I 15.636 I 3.089 4.508 1.533 0.271 0.205 0.063 0.058 0.008 0.050 0.970 0 2117.258 1.2615 36.537 

Averages: I 0.7695 I 2.531 I 0 I 21.422 I 23.417 I 28.0575 I 3.691 I 11.6655 I 2.1635 I 3.115 I 1.6515 I 0.3855 I 0.2555 I 0.0595 I 0.0735 I 0.01 I 0.0525 I 0.6795 I 0 L~ !.0942S1H.6925 

Note: An calculations were preformed by Precision An.lysis using physical constants from GPA·2145-09. 
• 

• 

• 

• 

29 Country Acres Rd, RIII.non, WY 82501 PRECISION/"' 0 ..11...: _.Pr_I.lo..-l.8....com

E-mall!.nfo4\lPr.c:I.lo..·U....com 

- .~s Toll Fl'e. Humb.... 1866, 98500866

Client: 

Sample 10: 

Unique #: 


Sample Temperature: 


Sampled By: 


County: 


BISON ENGINEERING 

WILLIAMS 

PENNINGTON 16-15 

57 DEG F 

TC 

DUNN 

Components Mole % 

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


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


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


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


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


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


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


n-ButanE~ ...................... 


iso-Pentclne .................. 


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


Cyclopentane ............... 


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


Cyclohexa ne ................ 


Other Hexanes ............. 


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


Methylcyclohexa ne ........ 


2,2,4-Trimethylpentane ... 


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


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


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


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


C8+ Heavies ................ 


Totals ........................ 


0.612 

0.000 

4.459 

53.689 

20.s55 

13.906 

1.188 

3.555 

0.461 

0.611 

0.031 

0.121 

0.058 

0.443 

0.134 

0.045 

0.000 

0.019 

0.026 

0.003 

0.014 

0.072 

100.000 

Weight % 

1.003 

0.000 

4.652 

32.081 

23.021 

22.839 

2.571 

7.695 

1.238 

1.641 

0.081 

0.389 

0.181 

1.423 

0.500 

0.166 

0.000 

0.056 

0.089 

0.012 

0.055 

0.306 

100.000 

AnalYSis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


Liq. Vol. % 

0.490 

0.000 

2.300 

42.686 

25.781 

17.967 

1.823 

5.256 

0.790 

1.038 

0.043 

0.234 

0.092 

0.855 

0.290 

0.086 

0.000 

0.025 

0.041 

0.005 

0.025 

0.173 

100.000 

10/11/2011 

10/11/2011 

40 PSI 

ONLINE 
• 


ADDITIONAL BETX DATA 

Components Mole % Weight % Liq. Vol. % 

Cyclopentane 0.031 0.081 0.043 

Cyclohexane 0.058 0.181 0.092 

2-Methylpentane 0.279 0.895 0.538 

3-Methylpentane 0.164 0.527 0.317 

• 

n-Hexane 0.121 0.389 0.234 

Methylcyclohexane 0.045 0.166 0.086 

2.2.4-Trimethylpentane 0.000 0.000 0.000 

Benzene 0.019 0.056 0.025 

Toluene 0.026 0.089 0.041 

Ethylbenzene 0.003 0.012 0.005 

m-Xylene 0.002 0.009 0.004 

p-Xylene 0.009 0.037 0.017 

o-Xylene 0.002 0.009 0.004 

SPECIFIC GRAVITY @60/60 F, calculated ................................................... 


TOTAL GPM (Ethane Inclusive) ................................................................. 


CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis.................................. 


CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis .................................. 


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


MOLAR MASS RATIO.............................................................................. 


RELATIVE DENSITY ( G x Z (Air) / Z ), calculated ........................................ 


IDEAL GROSS HEATING VALUE, BTU / IDEAL CF @14.696 PSIA .................. 


COMPRESSIBIlJTY FACTOR (Z) .............................................................. 


PROPANE GPM ..................................................................................... 


BUTANEGPM ....................................................................................... 


GASOlJNE GPM (PENTANE AND HEAVIER) ........................................... 


:\OT \TIO~ \LL l \Lll !-\TI( '''', I'ER]-( lR\ILn l SI'-:C, PHYS/( -\1 (O:\ST-\"rs fRO,\\ GPA 2145-\1'" THF T -\(JU5 

• 

Of I'HYSH ,-\1 U l"-T -\"T:; r( lit HYDRUC "RHO"S ,\"D UTHER c( ).\II'( ll"m. 01 I"TFRFST 

TO THr \:\11 R-\1 (,\5 p;m STR\ 

• 

• 

• 

• 

• 

Z9 Country Acres Rd, RIverton, WY 825D1 PRECISION:? Online: _.Pr.cl.lon·~b••com

E-mail.lnfoC!)Precl..lon·~b...com 

- ~SYS Toll Free Numbe.. (866) 985~866 

Client: 


Sample 10: 


Unique#: 


Sample Temperature: 


Sampled By: 


County: 


BISON ENGINEERING 

WILLIAMS 

MARY RSMITH 

72 DEG F 

TC 

DUNN 

Components Mole % 

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


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


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


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


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


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


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


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


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


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


Cyclopentane ............... 


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


Cyclohexane ................ 


Other Hexanes ............. 


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


Methylcycfohexane ........ 


2,2,4-Trimethylpentane... 

BenZenE!...................... 


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


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


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


C8+ Heavies ................ 


Totals ........................ 


0.445 

'0.000 

0.535 

24.513 

28.935 

27.572 

3.024 

9.829 

1.564 

2.184 

0.102 

0.411 

0.075 

0.545 

0.099 

0.028 

0.000 

0.030 

0.023 

0.003 

0.017 

0.066 

100.000 

We!s:ht % 

0.536 

0.000 

0.410 

10.763 

23.813 

33.276 

4.811 

15.636 

3.089 

4.313 

0.195 

0.970 

0.172 

1.287 

0.271 

0.074 

0.000 

0.063 

0.058 

0.008 

0.050 

0.205 

100.000 

Analysis Date: 


Date Sampled: 


Purpose: 


Sample Pressure: 


Type Sample: 


Liq. Vol. % 

0.296 

0.000 

0.230 

16.208 

30.180 

29.626 

3.860 

12.086 

2.231 

3.088 

0.118 

0.660 

0.099 

0.875 

0.178 

0.043 

0.000 

0.032 

0.030 

0.004 

0.026 

0.131 

100.000 

10/11/2011 

10/11/2011 

20 PSI 

ONLINE 
• 


ADDITIONAL BETX DATA 

• 

Components Mole % Weight % Liq. Vol % 

Cyclopentane 0.102 0.195 0.118 

Cyclohexane 0.075 0.172 0.099 

2-Methylpentane 0.343 0.810 0.551 

3-Methylpentane 0.202 0.477 0.324 

n-Hexane 0.411 0.970 0.660 

Methylcyclohexane 0.028 0.074 0.043 

2,2,4-Trimethytpentane 0.000 0.000 0.000 

Benzene 0.030 0.063 0.032 

Toluene 0.023 0.058 0.030 

Ethylbenzene 0.003 0.008 0.004 

m-Xylene 0.003 0.008 0.004 

p-Xylene 0.012 0.034 0.018 

o-Xylene 0.003 0.008 0.004 

SPECIFIC GRAVITY @ 60/60 F, calculated................................................... 


TOTAL GPM (Ethane Inclusive) ................................................................. 


CALCULATED BTU / REAL CF @ 14.73 PSIA, dry basis.................................. 


CALCULATED BTU / REAL CF @ 14.73 PSIA, wet basis .................................. 


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


MOLAR MASS RATIO............................................................................. . 


RELATIVE DENSITY ( G x Z (Air) / Z ). calculated ........................................ 


IDEAL GROSS HEATING VALUE, BTU / IDEAL CF @ 14.696 PSIA .................. 


COMPRESSIBIUTY FACTOR (Z) .............................................................. 


PROPANE GPM ..................................................................................... 


BUTANEGPM ..................................................................................... .. 


GASOUNE GPM (PENTANE AND HEAVIER) ........................................... 


'>;( n \Tl()~, \L1 (,\Let 1 \n()~~ PF!{H lR\IED L SI'-:(, PH)',I( \1 « l~~'j\"T~ !'RO~I CI',\,14',"': IHI I \BI E.'­

• 

Or PHYSl( \J U 1~5T \~ TO' H lR H\ DR()( \!{[I( ''''\'il) OTIII',R ( (t'\IP01'\l), Or I~TL!{rYI 

rOTHL "\Tl K\I C,,\, !"l)l 5TI\\ 

• 


1.2615 

21.293 

2111.258 

2081.086 

36.537 

1.2615 

1.2771 

2086.694 

0.98783 I

I 

r: 

f 

7.5766 


4.0779 


1.9202 

• 


ATTACHMENT F: ENGINE MANUFACTURER'S SPECS 


• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
This section of the document has been redacted because it 

contains copyrighted information. The redacted information 

can be viewed from the hard copy of the docket, which is 

available at the EPA Region 8 Office upon request. 
• RENTAL 	 C.i.TERPILLAR· 

Arrangemant shown 

with optional tl'lliler 

• 

FEATURES 

EMISSIONS 

• 	EPA Tier 3 and CARB Emissions Certified for 

non-road mobile applications at all 60 Hz and 

50 Hz ratings 

CAT C9 ATAAC DIESEL ENGINE 

• Utilizes ACER,.. 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 ACIDC, 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 

XQ230 

SOUND ATTENUATED 

DUAL VOLTAGE 

50/60 Hz 

ENVIRONMENTALLY FRIENDLY DESIGN 

• Sound attenuated for low noise operation 

• OSHA compliant safe design 

• 	110% spill containment for coolant and oil 

• UL142 certified dual wall fuel tank 

MULTI-VOLTAGE DISTRIBUTION PANEL 

• Simultaneous dual voltage 

• Load door safety switch 

• Rust-free hinges on all doors 

• Adequate space for line and plug connection 

without interference 

• Remote start and stop contacts 

SINGLE-SOURCE SUPPLIER 

• Complete systems designed at Caterpillar 

ISO 9001:2000 certified facilities 

• 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. 

LEHE5329-03 

• 

FACTORY INSTALLED STANDARD AND OPTIONAL EQUIPMENT 


•

RENTAL C.l.TERPILLAR­

• 

• 

• 

STANDARD FEATURES 

Air Inlet System Air cleaner. dual element 

Turbocharger 

Charging Systam 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 

Enelollure Sound attenuated 

12-gauge steel 

lockable doors 

Separate vented battery compartment 

Single point lifting 

Exterior oil and water drains with interior valves 

Hidden exterior fuel drain 

Hand holds and steps 

Powder coated finish 

Fuel System Primary fuel filter/Water separator 

Ul142 dual wall fuel tank 1667 l (440 gal) 

Radiator-mounted fuel cooler 

Generator Brushless. permanent magnet 

Coastal corrosion protection 

Shock mounted VR6 voltage regulator 

Space heater 

UL approved 

Simultaneous three-phase 480/277 and 

240/139 voltage 

Mounting System Generator soft mounted to base 

Base contains Integral fuel tank 

Skiddable structural steel design 

110% oil and coolant spill containment 

Starting System Electric starting motor 

Battery set with disconnect switch 

Jacket water heater with thermostat. 

shut-off valves 

opnONAl 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 surfece on steps 

Heavy duty safety chains and 

grab hooks 

Reinforced 4540 kg (10,000 Ibl top 

wind drop jack 

LEHE5329-03 2 
• RENTAL 

SPECIFICATIONS 

CAT SR4B GENERATOR 

Frame size •.........•.•.....•.••••••.•..•.••.....•••.• 449 

Type.•....•.•.....••........•. Permanant 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 .......•...••••...•:1: %% steady state/:I: %% no loed to fuilioed 

TIF ........................................... Less than 50 

THO ••...•..•..•.••••......•••.•••••••••..••• Less than 6%

• 

TECHNICAL DATA 

• 


ENGINE 

C9 ATAAC, 4-stroke-cycle watercooled diesel 

Bore - mm lin) .•........•••••.••....•••••••••... 112 (4.41) 

Stroke - mm (inl ................................ 149 (5.B7) 

Displacement - L Icu in).......•••••••••...• " ••••. B.8 (637) 

Compression ratio •. "" .....•••.••••••..•••••••••.•. 16.1:1 

Aspiration...••••.•..•.••.•• Turbocharged AA charge cooled 

Engine control .••••.......••...•••••••••••••••• ADEMltO A4 

CAT CONTROL PANEL - EMCP 3.2 

24 Volt DC Control 

NEMA 1, 1P22 enclosure 

Lockable hinged door 

Enclosure mounted 

Single location customer connector point 

16 light alarm module with alarm hom 

Electric fuel level gauge 

Consult your Caterpillar dealer for available voltag... 

X0230 

Power Rilling 

60Hz 

50 Hz 

ekW 

kVA 

StllncI>Y lMIRef. PrIme 1M ..... 

230 DM8502 210 DM851Z 

276 DMaI504 

EngIne and Container Information 

Engine model 

Container dimensions 

C9 

see chart on3)8ge 6 

Shipping Weight lOry) 

Unit with trailer kg Ub) 6210 (13,6901 

Unit without trailer 

Maximum Fuel Capacity Weight 

kg lib) 4980 (10,980) 

Unit with trailer kg Ubi 7506 (16,5501 

Unit without trailer kg Ub) 6278 (13,8401 

Engine Lubricating 011 Capacity 

Engine Coolant Capacity with Radiator 

Fuel Tank Capacity 

L (gal) 

L(gall 

L(gal) 

40 (10.551 

36 (9.6) 

1516 (400) 

Fuel Consumption lJhr (gal/hr) 69.2 (18.31 6U(17.1) 

Fuel Consumption 176'110 PrIme) lJhr (gal/hr) 50.6 (13.41 

Running TIme @ 76% Prime 

SoundllMll 

hours 28 

Standby dB(AI 74.72 

No loed 0 7 m (23 ftl dB(AI 70.20 

Prime dB(A) 73.49 

Ambient Capability Deg C (Deg FI 43 1109.4) 

• 


LEHE5329-03 3 

f 

I 

i

t 

i 
•

RENTAL 	 C.ATERPILLAR~ 

• 

• 

• 

RATING DEFINITIONS AND CONDITIONS 

Meets or Exceeds International Specifications: 

• 	NEMA MG1-32, IEC 60034, CSA, 98/37/EEC, 72123/EEC, 

UL 508, UL142,1503046/1,1508528, 89/336/EEC 

Standby - Output available with varying load for the 


duration of the interruption of the normal source power. 


Standby power In accordance with 1508528. Fuel stop power 


in accordance with IS0304611, A82789. DIN6271. and 855614. 


Prime - Output available with varying load for an unlimited 


time. Prime power in accordance with 1808528.10% overload 


power ill accordance with 1803046(1, AS2789, DIN6271, and 


885514 available on requesl 


Ratings are based on SAE J1349 standard conditions. 

These ratings also apply at 1503046/1, DIN6271, and B55514 

standard conditions. 

Fuel rates are based on fuel oil of 35° API (@ 16° C 160· Fll 

gravity having an LHV of 42 780 k.llkg 118,390 Btullb) when used 

at 290 C 1850 F) and weighing 838.9 gIIiter (7.001 IbJU.5. gal). 

Additional ratings may be available for specific customer 

requirements. Consult your Caterpillar representative for details. 

lEHE5329-03 	 4 
• RENTAL 	 C.TERPILLARDISTRIBUTION PANEL 


• 

r ."G.!!!!.-,... -----.... 

CATERPILLA 

, 

I :.: .; - _J-_.j' :::}!y.• c'·' 11 .. - , F. 

~~ @f 

•

• 


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 (W) ground stud 

16. Dual voltage load connection bus board 

[6.35 mm x 101.6 mm x 101.6 mm 


(y.,. x 4" x 4·) bus bars] 


LEHE5329-03 	 5 

• 

•

RENTAL C.TERPILLARe 

CONTAINER DIMENSIONS - TOP VIEW 


212.8 (lo.74J-+--;--; 

2540.0[100.00) 

o 

• ~--------------~·1{~r---------------~ 

• 

• 

CONTAINER DIMENSIONS - RIGHT SIDE VIEW 


t---.ZlB3.1 (93.84{ 

:l:2.25} 

Overall Dimensions 

Package With Trailer 

Length 4597.4mm 181 in 6248.3 mIT! 246 in 

Width 1498.6 mm 59 in 2640.0mm 100 in 

Height 2387.6mm 94 In 2882.8 inm 113.5 In 

LEHE5329·03 6 
• 

ATTACHMENT B: EMISSION INVENTORY 

• 


I

;. 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 
• 

• 

• 

• 
• 


ATTACHMENT G: EMISSION CONTROL DEVICE 

MANUFACTURER'S SPECS 

• 


• 


Dakota·3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• 

• 

• 

• 
c..... 


• 

• 

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 . 

• 

• 


I 

f 

~ 

H&me oWe.: 1-(560) 336·5496 FAX 1-(S8C) US·CSSS P.O. Box 1406, Guym&n, Oklahoma 73942 

Administrati... Office; 1·{40S) 926·7373 FAX H40!} 928-1380 P.O. Soo 7221 to. Norma". OI<.I.homa 73070 

I 
\ 

.:w:J2~ 

<w1I 

• 

C) MI:~l~J 

Il£SI:o 

• 

POOR 

NUt» 

48" DlA x 302 Sift' H6GHT, 88 ORlACES 

EMISSION CONTROL 0EVlCE 

.. >98% WOC ORE, CERTlFlED USEPA 40 CFR 

60, APPENDIX A, SClUR.CE fMfIIISIONS TEST 

METHODS REfERENC.E>. MEETS ALL EPA &; 

CDPHE REGULATIONS. 

.. DESlROYS OILiCONOfNSATE PRODUCTION 

TANK VAPORS WI NO VISIBLE RAME ,. EXCEUHIT OPACITY AND SMOKELESS 

OPERATION. 

• REI.1ABlf AND CUSTOMIZABLE IGNITlON. 

'" \/ERY lOW CAPITAL AND OPERATING COST. '" fAS( TO OPERATE AND MAINTAIN. .. WIll DESTROY UP TO 150 MCFD @ 10 0Zf11 J 

• 

"""'lID"'''''. ~ 

I:IID' -E---~~-~!:'llll'--IL------:-:c .- lINLBlI_iI'KftII I ~-~_!KIlON_.,.v:0I't'

~~~,~~ 1·~":=:~f5.,~!!"" I CIMARRON ~Joc. 

.. 

~ 

hi: l5OlSQO.6t 

oeIC: 
• 


ATTACHMENT H: PROCESS FLOW DIAGRAM OF 


FACILITY 


• 


• 


Dakota-3 E&P Company, LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• • 

---------------

-------

TYPICAL VAN HOOK AREA 


SEVEN WELL PAD FACILITY PLOT PLAN 


Dakota-3 E&P Company, LLC 


FBIR, North Dakota 


NOT TO SCALE 


8 Tonk Vent ..... 

Enclosed 

Combustnr

~",""" ,-----------"--.-" -~=---]I ----------"--.---­ - - - ~ - -.-. 7- .., - - - - ~. - - - - - - - :1 


6'dx20'h ___",..d "'-0-~.~ 1 I 


---i-+' 

.. I.., I. I,I, Ra:yclo Line -__ ::~::;==::::: =~:.:.:..tO. .., .............. -_4 _ .. ____ .~==== ====== ===_ -----" 

Berms !!!!!!!!!! WaterLine 


Crude Lioe 


Flowline 


Buried Recycle Lines 


Gas Sale. Line 


Tarok Vapor Lioe 


Flared G.. Lioe 


• • 

Gas Meter 

~ r- - - - - - _.. - - - - - - - .. 

Gas 10 sales 

.~ : 

1 


.,..... r~ ... 1 Valvo I 


I 1
 ""'-·1 1 


1 
 . - ~ I I 


- ~ __ ~ I 


~ 1 C><I"~ -i- .1 Valvo I 


1 


1 


1 


1 


" I I
 -i--I-t>¢.: GasMelc< 

I I Valve .... - -..c:::;::J 
 ., - ~ I
 1 . I 


1 


1 
 . ..., I I 


-'--I-~.: .. 1 Valvo 

.... -)

1 


1 


1 


1 
 i
 I 1 I 
 Utilily Flare - ~.; -11':;1- ~ 

I I Vain I
 --·1 

1 


1 


1 I 


1 I 
 I I 


-i~.j"l'"'::t-~ 1 I 


.:.. I Valve 

1 


1 


.. 1 
 I 


- - - LI><l-. 

1 
Valvo 

'~~~.....~"""~,l',.~.* ~~~~~~~... --~~...~~~~r_~~J~~~~""<Y;_..,~""~~~""""!".. 
ATTACHMENT I: PRODUCTION DECLINE CURVE 

CALCULATIONS 

I

• 


• 


• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
ATTACHMENT J: DIESEL TANK EPA TANKS 4.09D 

EMISSIONS SUMMARY 

• 


Dakota-3 E&P Company. LLC. 

NSR Synthetic Minor Application 

WEP211324 

• 
• TANKS 4.0 Report • • Page 1 of6 • 

Identification 

User Identification: 

City: 

State: 

Company: 

Type of Tank: 

Description: 

Tank Dimensions 

Shell Length (ft): 

Diameter (ft): 

Volume (gallons): 

Turnovers: 

Net Throughput(gal/yr): 

is Tank Heated (y/n): 

Is Tank Underground (y/n): 

Paint Characteristics 

Shell Color/Shade: 

Shell Condition 

Breather Vent Settings 

Vacuum Settings (psig): 

Pressure Settings (psig) 

TANKS 4.0.9d 


Emissions Report - Detail Format 


Tank Indentlflcation and Physical Characteristics 


1000 gallon diesel tank 

Williston 

North Dakota 

Williams E&P, LLC 

Horizontal Tank 

1,000 gallon diesel tank 10 fuel onsite diesel generators. Tank throughput is based on engine fuel consumption. 

10.00 

4.16 


1,000.00 


2,244.31 


2,244,312.00 

N 

N 

Gray/Medium 

Good 

·0.03 

0.03 

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

fil~:/Ir:\Propram Fil~s\Tanks40QrI\sl1mmarvrlisnlav.hfm 9/29/2011
• • • 

TANKS 4.0 Report Page 2 of6 

TANKS 4.0.9d 

Emissions Report· Detail Format 

Liquid Contents of Storage Tank 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

MixlUrelComponenl Monlh 

Daily liquid Surf. 

Temperalure (dog F) 

Avg. Min. Max. 

liquid 

Bulk 

Temp 

(degF) 

Vapor Pressure (psis) 

Avg. Min. Ma.. 

Vapor 

Mol. 

Weight. 

liquid 

Mass 

Fracl 

Vapor 

Mass 

Fract . 

Mol. 

Welghl 

Ba.lslor Vapor Pressure 

Calculallons 

.--..-----~------------------- ----

Disliilale fuel 011 no. 2 All 50.18 39.72 60.64 44.68 OJ)045 00031 0.0067 130.0000 188.00 ()pilon 1: VP50 •.0045 VP60 = .0065 

file:llr:\ProlYram Files\Tanks409c1\sn.marvclisnlav.htm 9/2912011
• • • • 

TANKS 4.0 Report Page 30f6 

TANKS 4.0.9d 

Emissions Report· Detail Format 

Detail Calculations (AP-42) 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

Annual Emission Calcaulallons 

Standing Losses (Ib): 

Vapor Space Volume (cu It): 

Vapor Density (Ib/cu II): 

Vapor Space Expansion Factor: 

Vented Vapor Saturation Factor: 

Tank Vapor Space Volume: 

Vapor Space Volume (cu It): 

Tank Diameter (II): 

Effechve Diameter (II): 

Vapor Space Outage (ft): 

Tank Shell Length (II): 

Vapor Densily 

Vapor Densily (Ib/cu II): 

Vapor Molecular Weight (lbnb-mole): 

Vapor Pressure at Daily Average Liquid 

Surface Temperature (psia): 

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

Daily Average Ambient Temp. (deg. F): 

Ideal Gas Constant R 

(psia cull / (!b.mol-deg R)): 


liquid Bulk Temperalure (deg. R): 


Tank Pain! Solar Absorptance (Shell): 


Daily Total Solar Insulation 


FaClor (Btu/sqll day): 

Vapor Space Expansion FaClor 

Vapor Space Expansion Factor: 

Dally Vapor Temperature Range (deg. R): 

Daily Vapor Pressure Range (psla): 

Breather Vent Press. Sel1lng Range(psla): 

Vapor Pressure al Daily Average liquid 

Sur1ace Temperature (psle): 

Vapor Pressure al Daily MInimum Liquid 

Sur1ace Temperature (psla): 

Vapor Pressure at Dally Maximum Liquid 

Sur1ace Temperature (psla): 

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

Daily Min. Liquid Sur1ace Temp. (deg A): 

Daily Max. liquid Surface Temp. (deg A): 

Daily Ambient Temp. Range (deg. R): 

Venled Vapor Saturation Fador 

Venled Vapor Saluration Fador: 

Vapor Pressure at Dally A_age Liquid: 

Sur1ace Temperature (psle): 


Vapor Space Outage (It): 


Working Losses (Ib): 

Vapor Molecular Weighl (lbnb.mole): 

vapor Pressure al Oally Average Liquid 

Surface TemperalUre (psia): 


Annual Nel Throughput (gallyr.): 


0.2654 

66.5719 

0.0001 

0.0180 

0.9995 

86.5719 

4.1600 

1.2191 

2.0800 

10.0000 

0.0001 

130.0000 

0.0045 509.8466 

41.5958 

10.731 

504.3458 

0.6800 

1.276.2450 

0.0160 

41.8377 

0.0036 

0.0600 

0.0045 

0.0031 

0.0061 

509.8466 

499.3812 

520.3060 

24.3583 

0.9995 

0.0045 

2.0600 

5.6720 130.0000 

0.0045 

2.244.312.0000 

fi1..·//r·\D.."",...,,.,... 1:<;1..,,\,..., ..lr"AfIOrI\ "n.......... ., .. .,rI;.....1.,,, ht...... QnQnm 1
 ----.--,-"-----­ -I!II-,-~ 
• • • 

TANKS 4.0 Report Page 4 of 6

Annual Turnovers: 2.244.3120 


Tumover Faclor: 0.1800 


Tank Diameter (fl): 4.1600 


Working Loss Product Facto,: 1.0000 


T olat Losses (Ib): 5.9375 

9/29/20\ \ filp·/lr·\PrrHl'r:lm Pilp<:\T:ln1c<:40QrI\<:nwml'lrvrli<:nll'lv htm 
• • • • TANKS 4.0 Report Page 5 of6 

TANKS 4.0.9d 


Emissions Report - Detail Format 


Individual Tank Emission Totals 


Emissions Report for: Annual 

1000 gallon diesel tank - Horizontal Tank 

Williston, North Dakota 

I 

IComponents 

II 

II Working LosslI 

Losses(lbs} 

Breathing LosslI 

I 

Total Emissionsl 

IDistiliate fuel oil no. 2 II 5.67\1 0.2711 5.941 

file:/IC:\Pro!!ram Files\Tanks409d\summarvdisnlav.htm 9/291201 t 
--

--

\0 

...... 

0 

\0 

Q) 

~ 

t'I$ 

Il.. 

t: 

0 

0.. 

Q) 

~ 

0 

-i: 

~ Z 

< 

Eo-< 

• 

-


~ 

~ 

0­

• 

.. 
 E

.s:. 

;:. 

« "

'" '1: 

C 

« 

[. 

--

;;; 

'1: 

0 

C 

"'-1 

..:.'" 

c 

--

E-

« 

'" $ 

t£ 

E 

<': 

\.. 

/) 

E 

Il. 

--:­

c... 

::::: 

$ 

l.C 

•