# Marathon

Oil C ompany 3172 Highway 22 North

Dickinson, ND 58601

Telephone 701.456.7500

Fa csimile 701.456.7525



# September 30 , 2011

**SENT VIA OVERNIGHT MAIL** 

Minor NSR Permitting Coordinator

U.S. EPA, Region 8

1595 Wynkoop Avenue, 8P

- AR

Denver, CO 80202

- 1129

RE: Oil and Gas Production Facility Application for New Construction



# Dear M s . P aser :

Enclosed, for your review, is a completed Oil and Gas Production Facility Application for New

Construction (Form NEW and Form SYNMIN)

, with attachments, for the M arathon Oil

Company facilit y listed below.

NDIC Permit Numbers Facility Name

TBD Maggie Old Dog USA 24

- 19H

Should you have any questions or if you need additional information, please contact me via

telephone a t 701

- 456

- 75 15 or via email at jajehn@marathonoil.com

.

Sincerely

, MARATHON OIL COMPANY



# John A. Jehn P.G.

Senior HES Professional

Bakken Asset, N orth A merican P roduction O perations

Cc: Joe Gillies J r.

, Environmental Director

Environmental Division

204 W. Main

New Town, ND 58763

- 9404

Cc: Tex Hall, Chairman Three Affiliated Tribes

404 Frontage Road

New Town, ND 58763

- 9404

# 



# 



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



# The following is a check list of the type of information that Region 9 will use to process information on your proposed

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

request approval and providing the information requested my 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 The Tribal Environmental Contact for the specific reservation:

U.S. EPA, Region 8

1595 Wynkoop Avenue, 8P-AR If you need assistance in identifying the appropriate Tribal

Denver, CO 80202-1129 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 FACILTY INFORMATION

1. (a) Company Name 2. Facility Name

(b) Operator Name

3. Type of Operation 4. Portable Source? Yes No

5. Temporary Source? Yes No

6. NAICS Code 7. SIC Code

8. Physical Address (home base for portable sources)

9. Reservation* 10. County* 11a. Latitude* 11b. Longitude*

12a. Quarter Quarter Section * 12b. Section * 12c. Township* 12d. Range*

*Provide all proposed locations of operation for portable sources 

# Proposed Construction of a New Facility UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

Region 8 Air Program

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY



# Check List - Application for New Construction

(Form NEW)

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

Proposed Construction of New Equipment at an Existing Facility

Proposed Modification of an Existing Facility



# Marathon Oil Company

Marathon Oil Company Maggie Old Dog USA 24-19H

Oil and Gas Extraction

211111 1311

3172 Hwy 22, Dickinson, North Dakota 58061

Fort Berthold McKenzie 47.791275 -102.632886

18 or 19 150 93

# 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)

Facility Name on the Permit

Permit Number (xx-xxx-xxxxx-xxxx.xx)

Date of the Permit Action

Facility Name on the Permit

Permit Number (xx-xxx-xxxxx-xxxx.xx)

Date of the Permit Action

Facility Name on the Permit

Permit Number (xx-xxx-xxxxx-xxxx.xx)

Date of the Permit Action

Facility Name on the Permit

Permit Number (xx-xxx-xxxxx-xxxx.xx)

Date of the Permit Action

Facility Name on the Permit

Permit Number (xx-xxx-xxxxx-xxxx.xx)

Date of the Permit Action

# C. CONTACT INFORMATION

Company Contact Title

Mailing Address

Email Address

Telephone Number Facsimile Number

Operator Contact (if different from company contact) Title

Mailing Address

Email Address

Telephone Number Facsimile Number

Facility Contact Title

Mailing Address

Email Address

Telephone Number Facsimile Number

Compliance Contact Title

Mailing Address

Email Address

Telephone Number Facsimile Number 

# (701) 456-7500 (701) 456-7525 Curtis Ryland Operations Manager

3172 Hwy 22, Dickinson, North Dakota 58061

cryland@marathonoil.com

Curtis Ryland Operations Manager

3172 Hwy 22, Dickinson, North Dakota 58061

cryland@marathonoil.com

(701) 456-7500 (701) 456-7525

John Jehn Senior HES Professional

3172 Hwy 22, Dickinson, North Dakota 58061

jajehn@marathonoil.com

(701) 456-7515 (701) 456-7525

# D. ATTACHMENTS

Include all of the following information (see the attached instructions)

FORM SYNMI N - 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 description 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 operationg 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 Polluant Emissions - Estimates of Current Acutal Emissions, Current Allowable Emissions, PostChange Uncontrolled Emissions, and Post-Change Allowable Emissions for the following air pollutants:

particulate matter, PM10, PM2.5, sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile

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

sulfuric acid mist (H2SO4), hydrogran 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 C of this form, as appropriate for the use specified at the top of the form.

D(i) - Proposed New Facility



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

sources, pursuant to CAA Section 302(j):

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

(b) Kraft pulp mills; (s) Secondary metal production plants;

(c) Portland cement plants; (t) Chemical process plants;

(d) Primary zinc smelters; (u) Fossil-fuel boilers (or combination thereof) totaling

(e) Iron and steel mills; more than 250 million British thermal units per hour

(f) Primary aluminum ore reduction plants; heat input;

(g) Primary copper smelters; (v) Petroleum storage and transfer units with a total

(h) Municipal incinerators capable of charging more than storage capacity exceeding 300,000 barrels;

250 tons of refuse per day; (w) Taconite ore processing plants;

(i) Hydrofluoric, sulfuric, or nitric acid plants; (x) Glass fiber processing plants;

(j) Petroleum refineries; (y) Charcoal production plants;

(k) Lime plants; (z) Fossil fuel-fired steam electric plants of more than

(l) Phosphate rock processing plants; 250 million British thermal units per hour heat input,

(m) Coke oven batteries; and

(n) Sulfur recovery plants; (aa) Any other stationary source category which, as of

(o) Carbon black plants (furnace process); August 7, 1980, is being regulated under section 111 or

(p) Primary lead smelters; 112 of the Act.

(q) Fuel conversion plants; 

# H2SO4

H2S

TRS 0.00 PM2.5

SOx 0.02

0.002

32.12

173.35

230*

0.00

0.00

0.00

0.00

0.00 0.002

32.12

173.35

0.00

0.00 0.00

0.00

0.00 10,219.14

0.00

0.00

0.00 RSC PM - Particulate Matter

PM10 - Particulate Matter less

than 10 microns in size

PM2.5 - Particulate Matter less

than 2.5 microns in size

SOx - Sulfur Oxides

NOx - Nitrogen Oxides

CO - Carbon Monoxide

VOC - Volatile Organic

Compound

Pb - Lead and lead compounds

NH3 - Ammonia

Fluorides - Gaseous and

particulates

H2SO4 - Sulfuric Acid Mist

H2S - Hydrogren Sulfide

TRS - Total Reduced Sulfur

RSC - Reduced Sulfur

Compounds 

# 0.02 0.02

0.02

0.02

NOx

CO

VOC

Pb

NH3

Fluorides (tpy) Proposed Allowable

Emissions

(tpy)

PM

PM10 0.02 Pollutant Potential Emissions

* Marathon Oil Company is requesting a facility-wide permit limit of 230 tpy for VOCs in this permit application. This limit will be

demonstrated by initially limiting production to 1,400 barrels of oil per day, on an annualized daily average, until a gas sale s line is installed and

functional. At that time Marathon will notify EPA of the gas sales line availability, that routine treater gas flaring has cea sed, and the 1,400 bopd

production limit will no longer apply. With gas sales the facility PTE will most likely be below Title V limits. With gas sal es, oil production

rates will be kept below 2,200 bopd, on an annualized average. VOC emissions at those rates will remain below the 230 tpy perm it limits as

shown on the attached calculations.

# D(ii) - Proposed New Construction at an Existing Facility or Modification of an Existing Facility

PM - Particulate Matter

PM10 - Particulate Matter less than 10 microns in size

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

SOx - Sulfur Oxides

NOx - Nitrogen Oxides

CO - Carbon Monoxide

VOC - Volatile Organic Compound

Pb - Lead and lead compounds

NH3 - Ammonia

Fluorides - Gaseous and particulates

H2SO4 - Sulfuric Acid Mist

H2S - Hydrogren Sulfide

TRS - Total Reduced Sulfur

RSC - Reduced Sulfur Compounds Post-Change

Actual Allowable Potential Pollutant Current Current Post-Change

Allowable

Emissions Emissions Emissions Emissions

(tpy) (tpy) (tpy) (tpy)

H2S

TRS

RSC SOx

NOx

CO

VOC

Pb

NH3 PM

PM10

PM2.5

Fluorides

H2SO4

# FORM NEW Maggie Old Dog USA 24

- 19H

D. Attachments September 30, 2011

 FORM SYNMIN

See the attached form and associated attachments (Form SYNMIN).

 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

.

Maggie Old Dog USA 24

- 19H will be owned and operated by Marathon Oil Company and is located

within McKenzie County

, North Dakota. The facility will be an oil and gas production facility

consisting of multiple wells, each well equipped with its dedicated heater treater, produced oil and

produced water storage tanks, treater utility flare and an enclosed combustor for th e tank vents.

Produced natural gas at the site is believed to be sweet but historically could contain up to 14 parts per

million of hydrogen sulfide ( H

2 

# S). The process flow diagram for each individual well that makes up

this facility is provided in Atta chment 1 and is described as follows:

1. Emulsion (comprised of produced oil, natural gas, and produced water) produced from the

production well casinghead (WELL HEAD) enters the 350,000 btu/hr Heater Treater

( HEATER TREATER ) for separation . The heater treat er is equipped with a heater treater

burner that is fueled by natural ( field) gas to separate the produced water, produced oil and

natural (field) gas.

2. Natural gas from the heater treater is either routed to the heater treater burner , or to an

external flare ( UPSET CONDITION GAS DESTRUCTION DEVICE ) with an estimated

destruction efficiency of 98% with a continuous automatic igniter is temporary

. This flare is

currently visually monitored. This flare also meets the flare velocity and gas btu requirement s

of 40 CFR 60.18.

3. Treater gas will only be flared temporarily until sales line installation is complete. Once the

sale line installation is complete, natural gas from the heater treater will be routed directly to

the sales line with 100% efficiency. The h eater treater flare will remain in place, but will only

be used in the event of an emergency upset condition. Attachment 3 to this application will

include the revised maximum production rate for this facility upon connection of the sales line

as a result of reduced admissions.

4. Produced oil from the heater treater is routed to approximately four (4) 400

- barrel

aboveground vertical fixed

- roof produced oil storage tanks (OIL TANK), where it is stored

prior to tanker truck loadout via submerged fill. The total number of tanks will vary and is

dependent upon capacity required for each well. Emissions from working/breathing/flash

losses from the produced oil tanks are routed to a combustor (GAS DESTRUCTION DEVICE)

with an estimated efficiency of 98% with a contin uous automatic igniter. The combustor is

equipped with an internal thermocouple to detect the presence of a flame, control operating

temperature, and to protect the combustor from potential overheating. In the event of

overheating leading to a high tempe rature emergency shutdown, the tank vent gas is routed

automatically to the treater utility flare until the combustor cools and is restarted. Emergency

shutdowns and run times are communicated to the Marathon main office via a telemetry

system.

# FORM NEW Maggie Old Dog USA 24

- 19H

D. Attachments September 30, 2011

5. If additio nal separation is necessary to further treat the produced oil in storage to meet buyer

specifications , one (1) electric 8

- horsepower recirculation engine pump, with one (1) 8

- hoursepower re

- circulating internal combustion engine (RICE) is used to re

- circulate the

produced oil from the tanks ba ck to the heater treater. This engine does not have any e mission

control devices at this tim e, but good operating practices are utilized to minimize any excess

emissions.

6. Produced water from the heater treater is routed to the one (1) 400

- ba rrel aboveground vertical

fixed

- roof produced water storage tank (WATER TANK)

, where it is stored prior to tanker

truck loadout. Emissions from the produced water ta nk are routed to the same combustor noted

above

.

2. The propos ed operating schedule present in terms of hours per day, days per week, and weeks per

year.

The proposed production facility will operate 24 hours per day, 7 days per week, 52 weeks per year for

a total of 8,760 hours per year. Exceptions to this operatin g schedule may include, but are not limited

to, emergency shutdowns due to weather conditions, scheduled maintenance, operation updates, and

temporary shut

- in if required.

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.

Table 1

– Fuels and/or Raw Materials Used on Site

Fuel and/or Raw Material Site Use

Produced Oil This site produces produced oil which is stored in the aforementioned

storage tanks prior to being taken off site via tanker truck. Production

volumes are shown on the attached calculation sheets.

Natural Gas Natural gas that is produced with the oil is separated and flared. A

portion of the gas (field gas) is used to fuel the burner for the heater

treater; composition of field gas is included in analytical results of

casinghead gas sampling included with this registration packet.

Production volumes are shown on the attached calculation sheets.

Produced Wate r Produced water associated with the production of oil and gas at this

facility is separated from the hydrocarbon streams in the heater treater

and routed to storage tanks prior to removal by tank truck.

 A process flow chart identifying all proposed p rocessing, combustion, handling, storage, and

emission control equipment (include the unit identification # or code). This flow chart should

illustrate the detailed narrative description requested above.

See the attached process flow diagram (Attachment 1). The following

- codes represent major pieces of

equipment in the proposed facility:

Table 2

– Facility Equipment Codes and Descriptions

Process Flow Diagram

Code Facility Equipment Description

WELL HEAD Location of the oil and gas well.

# FORM NEW Maggie Old Dog USA 24

- 19H

D. Attachments September 30, 2011

HEATER TREATER Heater treater and 350,000 btu/hr heater treater burner.

OIL TANK Four (4) 400

- bbl aboveground oil storage tank with a vertical fixed roof.*

WATER TANK One (1) 400

- bbl aboveground water storage tank with a vertical fixed roof.

RICE One (1) 8

- horsepower recirculation engine pump.

UPSET CONDITION

GAS DESTRUCTION

DEVICE Heater treater utility flare.

GAS DESTRUCTION

DEVICE Produced oil and produced water storage tank combustor.

*See the narrative description above

 List and describe all p roposed 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.

Table 3

– Hourly, Daily and Annu al Maximum Operating Rates for Each Operating Unit

Operating Unit Maximum Annual

Operating Hours

Produced Oil and Water Tank Combustor 8,760

Recirculation Engine Pump (RICE) 120

Heater Treater Burner 8,760

Heater Treater Flare 8,760

The projected average production at this facility is 1,400 barrels of oil per day (BOPD) and 1,400 Mscf

of natural gas per day. Upon completion of the sales line, as described in the narrative above, the

projected average is 2,200 BOPD and 2,200 Mscf of natural gas per day (Attachment 3). The projected

maximum production at this facility is 803,000 barrels of oil per year and 803,000 Mscf per year of

natural gas.

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

Table 4

– Hourly, Daily and Annual Maximum Firing Rates for Oil and Gas Materials for each

Combustion Equipment

Combustion Equipment Maximum Firing

Rates (in btu/hr) Maximum Annual

Operating Hours

Produced Oil and Water Tank Combustors 3.7 x 10 6



# (average btu/hr)* 8,760

Recirculation Engine Pumps (RICE) 8** 120

Heater Treater Burners 350,000 8,760

Heater Treater Utility Flares 37.5 x 10 6



# (average btu/hr)* 8,760

* These values were calculated in the calculation spreadsheet, which is based on multiplying the dry

heating input value and the scf/day value ( see Attachment 2 ).

** 8

- horsepower engine

# FORM NEW Maggie Old Dog USA 24

- 19H

D. Attachments September 30, 2011

3. The capacity for storage units and the hourly, daily and maximum throughput of material in the

storage units.

The maximum capacity of each produced oil and produced water storage tanks on site is 400 barrels.

Each produced oil tank is an aboveground steel tank with a fixed roof. The produced water tanks are

also aboveground and are fiberglass tanks that have fixed roofs. All tanks have vents to collect

working, breat hing and flash emissions which are collected and conveyed to the combustor.

Table 5

– Hourly, Daily and Annual Maximum Throughput of Materials to the Storage Tanks

Material Average Daily

Throughput

(in bbl/day) Annual Maximum

Throughput

(in bbl/year)

Produced Oil 1,400** 511,000

Produced Water 82.14* 29,981.1*

* Produced water is based on barrels of water per day (BWPD) and can vary significantly, depending

on timing of completion, days or years of production, etc. This value is based on 10 facilities within the

same prospect and was the highest of the facility produced water rates.

**See the narrative description above regarding sales line connection. If connected to sales, the

average daily production will be approximately 2,200 bbl/day and annual maximum throughput of

803,000 bbl/year.

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

of material and product.

See information provided from questions 1 through 3 above. In addition, refer to the facility narrative

description above and the associated process flow di agram ( Attachment 1).

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

and product.

See information provided from question 3 above.

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

annual and maximum hourly basis.

The proposed annual usage of field gas at this location is estimated at a maximum of 511,000 Mscf per

year. The anticipated hydrogen sulfide (H 2 

# S) content of this field gas (which fuels the treater burner

and is otherwise combusted in the treater flare) and tank emissions (which are combusted in the tank

combustor) are included in the analytical data in this registration packet. Actual H 2 

# S concentrations

data for gas produced at this facility is not yet available. However, based on projections, the gas is

potentially projected to have a H 2 

# S concentration of approximately 14 ppm.

 Type and quantity of raw materials used or final product produced proposed to be used on a

daily, annual and maximum hou rly basis.

See information regarding produced oil and natural gas production as provided in question 1.

# FORM NEW Maggie Old Dog USA 24

- 19H

D. Attachments September 30, 2011

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

number of weeks per year.

See information provided in question 2 above.

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

monitoring for each emission unit and air pollution generating activity.

Table 6

– Controls, Efficiencies, Limits and Monitoring fo r Each Emission Source/Activity

Emission Source Emission Controls Control

Efficiency Emission

Limit (in tpy) Monitoring Type

Produced

Oil/ Produced Water

Storage Tanks Combustor 98% See Note 1 Visual

combustor flame

presence

Heater Treater

Produced Natural

Gas Utility Flare 98% See Note 1 Visual flare

flame presence

Heater Treater

Burner Programmable Logic

Controller (PLC) 0%

(uncontrolled) See Note 1 See Note 2

RICE Engine None (uncontrolled) 0%

(uncontrolled) See Note 1 See Note 2

Truck Load out

(Produced oil and

produced water) Submerged Fill 0%

(uncontrolled) See Note 1 Wellview

Program oil

production rates

Pneumatic Pump None (uncontrolled) 0%

(uncontrolled) See Note 1 See Note 2

Pneumatic

Controllers None (uncontrolled) 0%

(uncontrolled) See Note 1 See Note 2

Note 1: See the attached calculation sheet for the emission limits in tons per year ( Attachment 2).

Note 2: This emission source has negligible emissions; visual monitoring can be conducted to check

for leaks and changes.

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

Manufacturer’s specifications for each pollution control device (combustor for control of tank

emissions and utility flare for produced gas combustion) are included in the attached materials

( Attachment 4). The utility flare used to control produced gas emissions from the heater treater is a

shop

- built flare device, and is designed to meet the flare velocity and gas btu requirements of 40 CFR

60.18

.

 Criteria Pollutant Emissions E stimates

See the calculation spreadsheet attached (Attachment 2).

 Modeling

– Air Quality Impact Analysis (AQIA)

There is no evidence at this time that this new construction would cause or contribute to a deterioration

of air quality.

 ESA (Endangered Species Act)

# FORM NEW Maggie Old Dog USA 24

- 19H

D. Attachments September 30, 2011

North Dakota Industrial Commission (NDIC) Oil and Gas Division rules require an Environmental

Assessment (EA) as a prerequisite to obtaining an oil drilling permit. Such assessments include or will

include best management practic es and proposed action plans to mitigate any potential impacts to

protected species/habitats.

 NHPA (National Historic Preservation Act)

Within the exterior boundaries of the Ft Berthold Indian Reservation (FBIR), and specifically for this

project, MOC has contracted a 3 rd 

# party professional archeologist in consultation with the Tribal

Historic Preservation Office (THPO), to conduct a Class III Cultural Resource Inventory Survey of the

lands affected by the proposed facility. In addition, as a precurs or to this survey and under the

direction of this professional archeologist, a search of the State Historical Society of North Dakota’s

site and manuscript files to ensure no previously recorded cultural resources are located within the

project area. In g eneral, should discovery of any culturally important resources occur during the

initial Class III survey, the project site is moved or abandoned to ensure there will be no impact to any

of these resources.

Consultation and clearance is required by NEPA f or wells that lie atop of federal surface lands or for

wells on fee simple surface lands that will cut federal minerals. This project has been approved by

either the BIA and/or the BLM with THPO concurrence prior to issuance of any permits and right of

way s for the project. In addition, MOC by way of an agreement with the Three Affiliated Tribes (TAT)

and THPO, has agreed to undertake the same methods and cultural resource surveys when

conducting operations on fee simple lands (within the exterior bounda ries of FBIR), where there are

no other federal actions necessary to obtain a permit to drill (APD).

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

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

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

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

replaced/updated after that review is completed.



# Please submit information to following two entities:

Federal Minor NSR Permit Coordinator The Tribal Environmental Contact for the specific reservation:

U.S. EPA, Region 8

1595 Wynkoop Avenue, 8P-AR If you need assistance in identifying the appropriate Tribal

Denver, CO 80202-1129 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 FACILTY INFORMATION

Company Name Facility Name

Company Contact or Owner Name Title

Mailing Address

Email Address

Telephone Number Facsimile Number



# B. ATTACHMENTS

For each criteria air pollutant, hazardous air pollutant and for all emission units and air pollutant-

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 of the 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 Greenhuose Gas (GHG) pollutants before and after proposed

emission controls UNITED STATES ENVIRONMENTAL PROTECTION AGENCY

Region 8 Air Program

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY



# Check List - Synthetic Minor Limit Request

(Form SYNMIN)



# Marathon Oil Company Maggie Old Dog USA 24-19H

generating activities to be covered by a limitation, include the following: 

# John A. Jehn Senior HES Professional

3172 Highway 22 North, Dickinson, ND 58601

jajehn@marathonoil.com

701-456-7515 701-456-7525

# FORM SYNMIN Maggie Old Dog USA 24

- 19H

B . Attachments September 30, 2011

Item 1

– The proposed limitation and a description of its effect on current actual, allowable and the

potential to emit.

This facility does not have a current permit that dictates the Current Actual Emissions or the Current

Allowable Emissions. For the Potential to Emit (PTE), s ee the attached calculation spreadsheet

( Attachment 2 ).

Item 2

– The proposed testing, monitoring, recordkeeping, and reporting requirements to be used to

demonstrate and assure compliance with the proposed limitation.

A c cording to 40 CFR §49.155(Minor NSR Rule), the following table identifies the testing, monitoring,

recordkeeping and reporting requirements for the facility:

Table 1

– Testing, Monitoring, Recordkeeping and Reporting Requirements

Facility

Equipment Testing

Requirements Monitoring

Requirements Recordkeeping

Requirements Reporting

Requirements

Heater treater

burner N/A N/A Maintain records

of burner rating N/A

Treater flare Initial s ample gas

composition N/A Maintain records

according to

40 CFR

§49.155(4)(i) Initial Submission

Treater flare N/A Monitor for flame

presence Maintain records

when flare is not

operating Annual

Treater flare N/A Visually monitor

for smoke

quarterly Maintain records

according to

40 CFR

§49.155(4)(i) Annual

Tank vent

combustor Initial sample gas

composition N/A Maintain records

according to

40 CFR

§49.155(4)(i) Initial Submission

Tank vent

combustor N/A Monitor for flame

presence Maintain records

when flare is not

operating Annual

Tank vent

combustor N/A Visually monitor

for smoke

quarterly Maintain records

according to

40 CFR

§49.155(4)(i) Annual

Produced Oil

Storage Tanks N/A N/A Maintain records

of oil production Report average

daily throughput

annually

8 hp recycle

engine N/A N/A N/A N/A

Item 3

– The type and quantity of fuels and/or raw materials used.

Table 2

– Fuels and/or Raw Materials Used on Site

# FORM SYNMIN Maggie Old Dog USA 24

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B . Attachments September 30, 2011

Fuel and/or Raw Material Site Use

Crude Oil This site produces crude oil which is stored in the aforementioned

storage tanks prior to being taken off site via tanker truck. Production

volumes are shown on the attached calculation sheets.

Natural Gas Natural gas that is produced with the oil is separated and flared or sold

via a gas pipeline. A portion of the gas (field gas) is used to fuel the

burner for the heater

- treater; composition of field gas is included in

analytical results of casinghead gas sampling included with this

registration packet. Production volumes are shown on the attached

calculation sheets.

Produced Water Produced water associated with the production of oil and gas at this

facility is separated from the hydrocarbon streams and routed to storage

tanks prior to removal by tank truck.

Item 4

– A description of estimated efficiency of air pollution control equipment under present or

a nticipated operating conditions, including documentation of the manufacturer specifications and

guarantees.

Historically a flare has been considered to meet the 98% control efficiency by demon strating that the

40 CFR 60.18 allowable tip velocity is not ex ceeded. 40 CFF 60.18(c)(4)(ii) allows non

- assisted flare

tip velocities from 60 to 400 feet per second if the net heating value exceeds 1,000 Btu/ std. cubic foot.

As shown on the attached gas analyses, the Btu content of both the treater gas (~1,500 Btu / sc

f) and the

tank vent gas (~2,200 Btu/scf) are well in excess of the 1,000 Btu/scf minimum requirement for a flare

tip velocity of up to 400 ft/sec.

Using a minimum treater flare tip diameter of 3 inches (0.049 ft 2 

# ) and a treater flare gas rate of

1,400 ,000 scf/day (16.2 scf/sec), the flare tip velocity can be calculated by from the gas volume in cubic

feet and the tip diameter in square feet. For this scenario, 16.2 scf/sec divided by the tip area of 0.049

ft

2 

# calculates to a flare velocity of 330 feet per second. Since this velocity is below the allowable 400

ft/sec, we believe demonstrates a 98% efficiency for the flare. Please note that while this

demonstration is for a three inch flare tip, it is possible the installed flare will have a larger tip

diameter that will further reduce velocities.

Item 5

– Estimates of the Current Actual Emissions, Current Allowable Emissions including all

calculations for the estimates, where applicable.

T

his facility does not have a current permit that dictates the Current Actual Emissions or the Current

Allowable Emissions. The potential to emit (PTE) value, as calculated in the attached calculation

spreadsheet ( Attachment 2) is 223.24 tons per year of VOCs.

Item 6

– Estimates of the Post

- Change Allowable Emissions that would result from compliance with the

proposed limitation, including all calculations for the estimates.

S imilar to Item 5, this facility does not have a current permit that dictates Current Actual Emissions or

the Current Allowable Emissions, so Post

- Change Allowable Emissions cannot be calculated at this

time.

Item 7

– Estimates of the potential emissions of Greenhouse Gas (GHG) pollutants:

1. Carbon Dioxide (CO2)

# FORM SYNMIN Maggie Old Dog USA 24

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B . Attachments September 30, 2011

2. Methane (CH4) and its CO2e

3. Nitrous Oxide (N2O) and its CO2e

4. Hydrofluor ocarbons (HFCs) and its CO2e

5. Perfluorocarbons (PFCs) and its CO2e

6. Su l fur hexafluoride (SF6) and its CO2e

Based on the estimated parameters for an oil and gas production facility in the state of North Dakota,

s ee the attached calculation spreadsheet ( Attachment 2 ).

# Attachment 1

– Typical Process Flow Diagram

# Attachment 2

– Current Calculations for EPA RegistrationGREEN= Requires inputRED= No input required. This is a calculated value.Facility InformationMaggie Old Dog USA 24-19HName of the facility, with well numbers (if known).TBDFirst date of production or the date of modification of the facility.9/30/2011Date registration packet is submitted to the NDDoH.Production Data DescriptionAnnual Avg BOPD1400This is the projected facility average BOPD on an annualized basisAnticipated GOR, scf/bbl1000Expected produced oil GORAnnual Avg Treater Gas (Mscfd)1400This is the calculated annual average mscfd of gas for the facility.Oil/Condensate Tank Data DescriptionFlash Gas Method: Default Bakken EFUse the drop down menu to choose the appropriate flash gas method.Bakken EF scf/bbl97.91The scf/bbl from direct measurement or representative sample. If specific data is not available, use the Bakken default of 97.91.Estimated Tank Vapors (scfd)137074This is the estimated scfd of tank vapors based on the following: adjusted BOPD multiplied by the scf/bbl entered under the Production Data sectionLower Heating Value2231Lower heating value (Btu/scf) of tank vapors. If site specific data is not available, use the Bakken default value of 2000.Molecular Weight44.11Molecular weight of the tank vapors in pounds per pound-mole (lb/lb-mole). If site specific data is not available, use the Bakken default value of 45.19.VOC%77.41%VOC weight fraction of the tank vapor gas (C3+). If site specific data is not available, use the Bakken default value of 79.8%.HAP%2.37%HAP weight fraction of the tank vapor gas. If site specific data is not available, use the Bakken default value of 2.26%.H2S weight %0.000%H2S weight percent of the tank vapor gas.H2S mole %0.000%H2S mole percent of the tank vapor gas.Enclosed Smokeless CombustorUse the drop down menu to choose the appropriate emission control type.Control Destruction Efficiency98%Control efficiency of any applicable controls. This is a fixed number based on control type.Treater Gas Data DescriptionBtu/scf1,612Btu/scf of wellstream gas.Molecular Weight28.46Average molecular weight of the wellstream gas in lb/lb-mole.Specific Gravity1If necessary to convert specific gravity to molecular weight, enter the specific gravity of the wellstream gas.Calculated Molecular Weight28.96This is the calculated molecular weight based on the specific gravity entered above.VOC%41.42%VOC weight fraction of the wellstream gas (Note: Weight%, not Mole%).HAP%3.50%HAP weight fraction of the wellstream gas. (Note: Weight%, not Mole%).H2S weight %0.000%H2S weight percent of the wellstream gasH2S mole %0.000%H2S mole percent of the wellstream gasUtility Flare or Other 98% DRE DeviceUse the drop down menu to choose the appropriate emission control type.Control Destruction Efficiency (DE 1)98%Control efficiency of any applicable controls (combustor, pit flare, utility flare, etc).Hours of Operation8760Hours of Operation at Destruction Efficiency 1Input Data6Attachment 2 - Calculations for EPA Air Registration.xlsx, Input1 of 369/30/2011Input DataTreater Burner(s) DescriptionTotal Btu/hr700,000Total burner rating for the heater treater burner(s) in btu/hr. If there are multiple burners, add the total heat input together.Hours of Operation8,760The burner(s) is/are assumed to operate 8,760 hours per year.Truck Loading DescriptionOil is hauled by truckUse the drop down menu to choose the appropriate oil sales method. If oil is sold through a LACT, no input values are requiredfor the Truck Loading DataSubmerged loading: dedicated normal service0.6Use the drop down list to choose the appropriate mode of operation. The saturation factor will automatically be selected basedon mode of operation.Molecular Weight44.11Molecular weight of tank vapors in lb/lb-mole. If no site specific data is available, please refer to Table 2 on the Truck Loading tab.Vapor Pressure1.90True vapor pressure of liquid loaded, pounds per square inch absolute (psia) If no site specific data is available, please refer to Table 2 on the Truck Loading tab.Temperature41.33Temperature of bulk liquid loaded in Fahrenheit. If no site specific data is available, use an estimated average annual temperature.Load Rate (bbl/hr)200Load rate of liquid loaded in barrels per hour.Load Time (hrs)1.00The time it takes to loadout one load (hrs).Pneumatic Pumps DescriptionNumber of Pneumatic Pumps2Number of pneumatic pumps at facility.Hours of Operation4380Hours the pump is in operation annually. For winter months only, please enter 4380 hours.scf/min0.50Pneumatic source consumption rate as per manufacturer data (scf/min).Vented to atmosphereUse the drop down menu to choose the appropriate emission control type.Control Efficiency0%Control efficiency of any applicable controls (combustor, routing exhaust to fuel supply, VRU, etc).Pneumatic Controllers DescriptionNumber of Pneumatic Controllers4Number of pneumatic controllers at facility.Bleed rate (scf/hr)17.40Average bleed rate of device (scf/hr).Glycol Dehydrator DescriptionVOC (TPY)0.00VOC emissions calculated in GRI-GLYCalc software (if no glycol dehydrator enter 0).HAP (TPY)0.00HAP emissions calculated in GRI-GLYCalc software (if no glycol dehydrator enter 0).6Attachment 2 - Calculations for EPA Air Registration.xlsx, Input2 of 369/30/2011Number of Engines2RICE Engine #1Hours of Operation120Maximum HP Rating8NOx g/hp-hr4.99CO g/hp-hr3.16VOC g/hp-hr6.8NOx Control Efficiency0%CO Control Efficiency0%VOC Control Efficiency0%RICE Engine #2Hours of Operation120Maximum HP Rating8NOx g/hp-hr4.99CO g/hp-hr3.16VOC g/hp-hr6.8NOx Control Efficiency0%CO Control Efficiency0%VOC Control Efficiency0%RICE Engine #3Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Input DataEnter the number of engines that will be installed at the production facility.DescriptionRecycle pump engine operates less than 10 hours per month.Manufacturer's maximum hp rating.DescriptionRecycle pump engine operates less than 10 hours per month.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.6Attachment 2 - Calculations for EPA Air Registration.xlsx, Rice Input 3 of 369/30/2011RICE Input DataRICE Engine #4Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #5Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #6Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #7Hours of Operation0NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.6Attachment 2 - Calculations for EPA Air Registration.xlsx, Rice Input 4 of 369/30/2011RICE Input DataMaximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #8Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #9Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #10Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.Manufacturer's maximum hp rating.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.6Attachment 2 - Calculations for EPA Air Registration.xlsx, Rice Input 5 of 369/30/2011RICE Input DataNOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #11Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #12Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).6Attachment 2 - Calculations for EPA Air Registration.xlsx, Rice Input 6 of 369/30/2011GREEN= Requires inputRED= No input required. This is a calculated value.Facility InformationMaggie Old Dog USA 24-19HName of the facility and the well number.TBDFirst date of production or the date of modification of the facility.9/30/2011Date registration packet is submitted to the NDDoH.Natural Gas Pneumatic Device Venting DescriptionCount - Total Number of Continuous High Bleed NaturalGas Pneumatic Devices2Count - Total Number of Continuous Low Bleed NaturalGas Pneumatic Devices0Count - Total Number of Intermittent Bleed Natural GasPneumatic Devices0Concentration in Produced Natural Gas - CH447%Concentration of CH4in produced natural gas. For facilities in 98.230(a)(3)-(a)(8), GHGi = 1Concentration in Produced Natural Gas - CO21%Concentration of CO2, in produced natural gas. For facilities in 98.230(a)(3)-(a)(8), GHGi = 1Associated Gas Venting and Flaring DescriptionGas to Oil Ratio (GOR)1000Gas to Oil ratio in cubic feet of gas per barrel of oil. Oil refers to hydrocarbon liquids produced of all API gravities.Volume of Oil Produced (barrels/year)511000Volume of oil produced in barrels in the calendar year during which associated gas was vented or flaredVolumetric Emissions - Gas Venting & Flaring DescriptionTemperature at standard conditions (°F)60Temperature at standard conditions (°F) - TsTemperature at actual emission conditions (°F)60Temperature at actual emission conditions (°F) - TaAbsolute pressure at standard conditions (psia)14.7Absolute pressure at standard conditions (psia) - PsAbsolute pressure at actual conditions (psia)13.6Absolute pressure at actual conditions (psia) - PaMole Fraction in Natural Gas - CH40.47Mole Fraction in Natural Gas - CO20.01115Gas Venting and Flare Stack Emissions DescriptionField Gas or Process Vent GasUse the drop down menu to choose the appropriate type of fuel vented.High Heat Value (HHV)1.235E-03Default High Heat Value based on 40 CFR 98 Table C-1 or 40 CFR 98.233(z)(6)(ii)Percent of Gas Flared100%Percent of gas sent to flare in cubic feet, during the yearFraction of Gas Combusted by Burning Flare98%Fraction of gas combusted by a burning flare (default is 0.98). For gas sent to an unlit flare, n is zeroMole Fraction of Methane0.47Mole fraction of gas hydrocarbon constituentsMole Fraction of Ethane0.26Mole fraction of gas hydrocarbon constituentsMole Fraction of Propane0.15Mole fraction of gas hydrocarbon constituentsMole Fraction of Butane0.0534Mole fraction of gas hydrocarbon constituentsMole Fraction of Pentanes-Plus0.03Mole fraction of gas hydrocarbon constituentsGHG Calculations Input Data1st Calendar Year - Count the total of each type, or count any percentage number of each type plus an engineering estimate based on best available data of the number not counted2nd Calendar Year - Count the total of each type, or count any percentage number of each type plus an engineering estimate based on best available data of the number not counted3rd Calendar Year - Complete the count of all pneumatic devices, including any changes to equipment counted in prior yearsFollowing Years - Update the total count of pneumatic devices and adjust accordingly to reflect any modifications due to changes in equipmentMole fraction of GHGi in the natural gas. 98.233(u)(2) - Annual average mole fraction for each facility as specified in 98.233(u)(2)(i)GHG mole fraction in produced natural gas for onshore petroleum and natural gas production facilities. If you have a continuous gas composition analyzer for produced natural gas, you must usethese values for determining the mole fraction. If you do not have a continuous gas composition analyzer, then you must use your most recent gas composition based on available sample analysisof the field.6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG Calculations Input 7 of 369/30/2011VOC NOx COSO2PMPM10PM2.5Oil/Condensate Tanks 45.08 3.80 20.65 -- -- -- --Treater Flare 158.92 28.02 152.44 0.00 -- -- --Treater Burner 0.02 0.30 0.25 0.002 0.02 0.02 0.02RICE Engine 0.01 0.01 0.01 0.00 0.00 0.00 0.00Truck Loading 10.38 -- -- -- -- -- --Pneumatic Pump 4.09 -- -- -- -- -- --Pneumatic Controllers 4.74 -- -- -- -- -- --Glycol Dehydrator 0.00 -- -- -- -- -- --Totals (TPY) 223.24 32.12 173.35 0.00 0.02 0.02 0.02PSD Threshold* 250 250 250 250 250 250 250Is Threshold Exceeded? No No No No No No NoPSD Modification Threshold* 40 40 100 40 25 15 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 100 100 100 100 100 100Is Threshold Exceeded?YesNoYesNo No No NoMinor NSR Rule Threshold*** 5 10 10 10 10 5 3Is Threshold Exceeded?Yes Yes YesNo No No NoPbNH3FluoridesH2SO4H2STRS RSCOil/Condensate Tanks -- -- -- -- -- -- --Treater Flare -- -- -- -- 0.00 -- --Treater Burner -- -- -- -- -- -- --RICE Engine -- -- -- -- -- -- --Truck Loading -- -- -- -- -- -- --Pneumatic Pump -- -- -- -- -- -- --Pneumatic Controllers -- -- -- -- -- -- --Glycol Dehydrator -- -- -- -- -- -- --Totals (TPY) 0.00 0.00 0.00 0.00 0.00 0.00 0.00PSD Threshold* 250 - 250 250 250 250 250Is Threshold Exceeded? No No No No No No NoPSD Modification Threshold* 0.6 - 3 7 10 10 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 - 100 100 100 100 100Is Threshold Exceeded? No No No No No No NoMinor NSR Rule Threshold*** 0.1 - 12222Is Threshold Exceeded? No No No No No No NoNotes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements**Title V Thresholds taken from the Major Source definition contained in 40 CFR 70.2***Minor NSR Rule Thresholds are found in Table 1 to 40 CFR 49.153, Minor NSR Thresholds (Attainment Areas)*PSD Threshold taken from 40 CFR 52.21(b)(1)(i)(b), oil and gas well facilities are not 1 of the 28 designated source categories listed in 40 CFR 52.21(b)(1)(i)(a) thus theapplicability threshold is 250 tpy. PSD Modification Thresholds taken from 40 CFR 52.21(b)(23)(i).Controlled Criteria Air Pollutants Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryEmission SourceREGULATED CRITERIA AIR POLLUTANTS PTE (TPY) - ControlledREGULATED AIR POLLUTANTS (TPY) - ControlledEmission SourceMarathon Oil CompanyMaggie Old Dog USA 24-19H6Attachment 2 - Calculations for EPA Air Registration.xlsx, Emission Summary - Controlled9/30/2011VOC NOx COSO2PMPM10PM2.5Oil/Condensate Tanks 2253.87 3.80 20.65 -- -- -- --Treater Flare 7946.03 28.02 152.44 0.00 -- -- --Treater Burner 0.02 0.30 0.25 0.002 0.02 0.02 0.02RICE Engine 0.01 0.01 0.01 0.00 0.00 0.00 0.00Truck Loading 10.38 -- -- -- -- -- --Pneumatic Pump 4.09 -- -- -- -- -- --Pneumatic Controllers 4.74 -- -- -- -- -- --Glycol Dehydrator 0.00 -- -- -- -- -- --Totals (TPY) 10219.14 32.12 173.35 0.002 0.02 0.02 0.02PSD Threshold* 250 250 250 250 250 250 250Is Threshold Exceeded?YesNo No No No No NoPSD Modification Threshold* 40 40 100 40 25 15 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 100 100 100 100 100 100Is Threshold Exceeded?YesNoYesNo No No NoMinor NSR Rule Threshold*** 5 10 10 10 10 5 3Is Threshold Exceeded?Yes Yes YesNo No No NoPbNH3FluoridesH2SO4H2STRS RSCOil/Condensate Tanks -- -- -- -- -- -- --Treater Flare -- -- -- -- 0.00 -- --Treater Burner -- -- -- -- -- -- --RICE Engine -- -- -- -- -- -- --Truck Loading -- -- -- -- -- -- --Pneumatic Pump -- -- -- -- -- -- --Pneumatic Controllers -- -- -- -- -- -- --Glycol Dehydrator -- -- -- -- -- -- --Totals (TPY) 0.00 0.00 0.00 0.00 0.00 0.00 0.00PSD Threshold* 250 - 250 250 250 250 250Is Threshold Exceeded? No No No No No No NoPSD Modification Threshold* 0.6 - 3 7 10 10 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 - 100 100 100 100 100Is Threshold Exceeded? No No No No No No NoMinor NSR Rule Threshold*** 0.1 - 12222Is Threshold Exceeded? No No No No No No NoNotes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements**Title V Thresholds taken from the Major Source definition contained in 40 CFR 70.2***Minor NSR Rule Thresholds are found in Table 1 to 40 CFR 49.153, Minor NSR Thresholds (Attainment Areas)*PSD Threshold taken from 40 CFR 52.21(b)(1)(i)(b), oil and gas well facilities are not 1 of the 28 designated source categories listed in 40 CFR 52.21(b)(1)(i)(a) thus theapplicability threshold is 250 tpy. PSD Modification Thresholds taken from 40 CFR 52.21(b)(23)(i).REGULATED CRITERIA AIR POLLUTANTS PTE (TPY) - UncontrolledEmission SourceMaggie Old Dog USA 24-19HREGULATED AIR POLLUTANTS (TPY) - UncontrolledEmission SourceUncontrolled Criteria Air Pollutants Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil Company6Attachment 2 - Calculations for EPA Air Registration.xlsx, Emission Summary - Uncontrolled9/30/2011CO2e CO2CH4N2OOil/Condensate Tanks & FugitiveEquipment Leaks****Negligible Negligible Negligible --Gas Venting (Flared)5.80E+04 5.60E+04 9.60E+01 --Gas Venting (Unflared) 0.00E+00 0.00E+00 0.00E+00 --Treater Burner325.44 325.12 0.13 0.19RICE Engine1.04 1.04 -- --Truck Loading-- -- -- --Pneumatic Pump45.27 0.14 2.15 --Pneumatic Controllers163.72 0.50 7.77 --Glycol Dehydrator-- -- -- --Totals (metric tons/year) 58,555 56,330 106 0.19GHG Reporting Threshold* 25,000 -- -- --Note: Subpart W requires reporting these emissions as part of the larger basin reporting.CO2e CO2CH4N2OOil/Condensate Tanks & FugitiveEquipment Leaks****Negligible Negligible Negligible --Gas Venting (Flared) 63955.80 6.17E+04 1.06E+02 --Gas Venting (Unflared) 0.00E+00 0.00E+00 0.00E+00Treater Burner 358.73 358.38 0.14 0.21RICE Engine 1.04 1.04 -- --Truck Loading -- -- -- --Pneumatic Pump 49.90 0.15 2.37 --Pneumatic Controllers 180.47 0.56 8.57 --Glycol Dehydrator -- -- -- --Totals (tpy) 64,545.94 62,093.36 116.91 0.21Title V Threshold** 100,000 -- -- --Is Threshold Exceeded? No -- -- --PSD Threshold*** 100,000 -- -- --Is Threshold Exceeded? No -- -- --Maggie Old Dog USA 24-19HGREENHOUSE GAS EMISSIONS PTE (metric tons/year)Emission Source***PSD Threshold for GHG taken from PSD and Title V Permitting Guidance for Greenhouse Gases prepared by the US EPAOffice of Air Quality Planning and Standards in March 2011. PSD applicability threshold is 75,000 tpy CO2e formodifications at existing PSD sources, 100,000 tpy CO2e for new sources and 100/250 tpy mass basis.**Title V Threshold for GHG taken from PSD and Title V Permitting Guidance for Greenhouse Gases prepared by the USEPA Office of Air Quality Planning and Standards in March 2011.Notes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPArequirements.*GHG Reporting Threshold taken from 40 CFR 98.2(3)(iii).GREENHOUSE GAS EMISSIONS PTE (tpy)Greenhouse Gas Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyEmission Source****Due to the nature of these types of emissions sources (i.e., oil/condensate tanks and fugitive equipment leaks) potentialemissions of regulated GHG emissions have been assumed to be negligible.6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG Emission Summary9/30/2011Total HAPs Benzene Toluene Hexane AcetaldehydeOil/Condensate Tanks 1.38 -- -- -- --Treater Flare 13.42 -- -- -- --Treater Burner 5.67E-03 6.31E-06 1.02E-05 5.41E-03 --RICE Engine -- -- -- -- --Truck Loading -- -- -- -- --Pneumatic Pump 0.35 -- -- -- --Pneumatic Controllers 0.40 -- -- -- --Glycol Dehydrator -- -- -- -- --Totals (TPY) 15.55 (no individual HAP exceeds 10 tpy)Title V Threshold* 25 10 10 10 10Is Threshold Exceeded? NoYesNo No NoNotes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.TreaterflareHAPs conservatively calculatedassuming allC6+ components areHAPs, as an extendedanalysis was not available.*HAP thresholds of 10 tpy of an individual regulated HAP and 25 tpy aggregate are taken from the Major Source definition contained in 40CFR 70.2. The thresholds of 10/25 tpy also represent what constitutes a major stationary source.REGULATED HAZARDOUS AIR POLLUTANTS PTE (TPY)Emission SourceMaggie Old Dog USA 24-19HHAP Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil Company6Attachment 2 - Calculations for EPA Air Registration.xlsx, HAP Emission Summary 9/30/2011Oil/Condensate Tanks Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HFlare Gas Volume(scf/day)Lower HeatingValue (Btu/scf)MolecularWeight(lb/lb-mole)VOC wt Fraction(%)HAP wtFraction (%)DestructionEfficiency (%)NOx EmissionFactor(lb/MMBtu)CO EmissionFactor(lb/MMBtu)137074.00 2231.38 44.11 77.41% 2.37% 98% 0.068 0.37PollutantFlare Gas Volume(scf/hr)scf/lb-moleMolecularWeight(lb/lb-mole)wt Fraction(%)Heating Value(Btu/scf)DestructionEfficiency (%)PotentialUncontrolledEmissions(lbs/hr)PotentialUncontrolledEmissions(tons/year)PotentialControlledEmissions(lbs/hr)PotentialControlledEmissions(tons/year)VOC 5711.42 0.0026 44.11 77.41% -- 98% 514.58 2253.87 10.29 45.08HAP5,711.42 0.0026 44.11 2.37% -- 98% 15.79 69.14 0.32 1.38NOx5,711.42-- -- -- 2231.38 -- 0.87 3.796 0.87 3.796CO5,711.42-- -- -- 2231.38 -- 4.72 20.65 4.72 20.65Notes:NOx& CO emission factors are from AP-42 Table 13.5-1 - Emission Factors for Flare Operations.Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirementsEmission estimates reflect combustion related air pollutants. If flare equipped with a pilot burner, heat input of burner should be evaluated.Example CalculationsVOC and HAPS EmissionsPotential Controlled Emissions (lbs/hr) = (Flare Gas Volume (scf/hr) * scf/lb-mole * Molecular Weight (lb/lb-mole) * wt Fraction (%)) * 1 - Destruction Efficiency (%)Potential Controlled Emissions (tons/yr) = Potential Controlled Emissions (lbs/hr) * 8760 hrs/yr * 1/2000NOx and CO EmissionsPotential Controlled Emissions (lbs/hr) = Flare Gas Volume (scf/hr) * Heating Value (Btu/scf) * 1/1,000,000 * Emission Factor (lbs/MMBtu)Potential Controlled Emissions (tons/yr) = Potential Emissions (lbs/hr) * 8760 hrs/yr * 1/20006Attachment 2 - Calculations for EPA Air Registration.xlsx, OilCondensate Tanks9/30/2011Treater Flare Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HFlare GasVolume (scf/day)Lower HeatingValue (Btu/scf)MolecularWeight(lb/lb-mole)VOC wt Fraction(%)HAP wtFraction (%)NOx EmissionFactor(lb/MMBtu)*CO EmissionFactor(lb/MMBtu)*DestructionEfficiency 1(%)**Hours ofOperation at DE 1(hours)DestructionEfficiency 2 (%)**Hours ofOperation at DE 2(hours)1,400,000.00 1612.49 28.46 41.42% 3.50% 0.068 0.37 98% 8760 100% 0PollutantFlare Gas Volume(scf/hr)scf/lb-moleMolecularWeight(lb/lb-mole)wt Fraction(%)Heating Value(Btu/scf)PotentialUncontrolledEmissions(lbs/hr)PotentialUncontrolledEmissions(tons/year)PotentialControlledEmissions 1(lbs)PotentialControlledEmissions 1(tons)PotentialControlledEmissions 2(lbs)PotentialControlledEmissions 2(tons)Potential TotalControlledEmissions(lbs/hr)Potential TotalControlledEmissions(tons/year)VOC 58,333.33 0.0026 28.46 41.42% -- 1814.16 7946.03 36.28 158.92 0.00 0.00 36.28 158.92HAP58,333.33 0.0026 28.46 3.50% -- 153.20 671.00 3.06 13.42 0.00 0.00 3.06 13.42H2S58,333.33 0.0026 28.46 0.00% -- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SO258,333.33 0.0026 64.00 0.00% -- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00NOx58,333.33-- -- -- 1612.49 6.40 28.02 -- -- -- -- 6.40 28.02CO58,333.33 -- -- -- 1612.49 34.80 152.44 -- -- -- -- 34.80 152.44Notes:*NOx& CO emission factors are from AP-42 Table 13.5-1 - Emission Factors for Flare Operations.**100% destruction efficiency means that the treater gas is routed and connected to the sales line (gas gathering pipeline).Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Example CalculationsVOC and HAPS EmissionsPotential Controlled Emissions (lbs/hr) = (Flare Gas Volume (scf/hr) * scf/lb-mole * Molecular Weight (lb/lb-mole) * wt Fraction (%)) * 1 - Destruction Efficiency (%)Potential Controlled Emissions (tons/yr) = Potential Controlled Emissions (lbs/hr) * Hours of Operation * 1/2000NOx and CO EmissionsPotential Controlled Emissions (lbs/hr) = Flare Gas Volume (scf/hr) * Heating Value (Btu/scf) * 1/1,000,000 * Emission Factor (lbs/MMBtu)Potential Emissions (tons/yr) = Potential Emissions (lbs/hr) * 8760 hrs/yr * 1/20006Attachment 2 - Calculations for EPA Air Registration.xlsx, Treater Flare9/30/2011Treater Burner Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HBurner Rating(Btu/hr)Burner Rating(MMBtu/hr)Average NaturalGas HigherHeating Value(Btu/scf)NOx EmissionFactor(lb/106scf)CO EmissionFactor(lb/106scf)PM (Total)Emission Factor(lb/106scf)PM(Condensable)Emission Factor(lb/106scf)PM (Filterable)Emission Factor(lb/106scf)SO2EmissionFactor(lb/106scf)VOC EmissionFactor(lb/106scf)HAP EmissionFactor(lb/106scf)700,000.00 0.70 1,020 100 84 7.6 5.7 1.9 0.6 5.5 1.9PollutantEmission Factor(lb/MMBtu)Burner Rating(MMBtu/hr)PotentialEmissions(lbs/hr)PotentialEmissions(tons/year)NOx 0.10 0.70 0.07 0.30CO0.08 0.70 0.06 0.25PM (Total)0.007 0.70 0.005 0.02PM (Condensable)0.006 0.70 0.0040.02PM (Filterable)0.002 0.70 0.001 0.006SO20.001 0.70 0.00040.002VOC0.005 0.70 0.0040.02HAPs0.002 0.70 0.001 0.006Notes:NOx, CO, PM, HAP, SO2 & VOC Emission Factors are from AP-42, Section 1.4 - Natural Gas Combustion, Tables 1.4-1, 1.4-2, and 1.4-3.Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Example CalculationsPotential Emissions (lbs/hr) = Emission Factor (lbs/MMBtu) * Burner Rating (MMBtu/hr)Potential Emissions (tons/yr) = Potential Emissions (lbs/hr) * 8760 hrs/yr * 1/20006Attachment 2 - Calculations for EPA Air Registration.xlsx, Treater Burner9/30/2011Treater Burner - Regulated HAPs Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HFormaldehyde Yes 7.35E-05 AP-42 Nat. Gas Comb. (7/98), Table 1.4-35.15E-05 2.25E-042-Methylnaphthalene Yes 2.35E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.65E-08 7.21E-083-Methylchloranthrene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-097,12-Dimethylbenz(a)anthracene Yes 1.57E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.10E-08 4.81E-08Acenaphthene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Acenaphthylene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Anthracene Yes 2.35E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.65E-09 7.21E-09Arsenic Yes 1.96E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.37E-07 6.01E-07Benz(a)anthracene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Benz(a)pyrene Yes 1.18E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-10 3.61E-09Benzene Yes 2.06E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.44E-06 6.31E-06Benzo(b)fluoranthene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Benzo(g,h,i)perylene Yes 1.18E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-10 3.61E-09Benzo(k)fluoranthene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Beryllium Yes 1.18E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-48.24E-09 3.61E-08Cadmium Yes 1.08E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-47.55E-07 3.31E-06Chromium Yes 1.37E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-49.61E-07 4.21E-06Chrysene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Cobalt Yes 8.24E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-45.76E-08 2.52E-07Dibenzo(a,h)anthracene Yes 1.18E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-10 3.61E-09Dichlorobenzene Yes 1.18E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-07 3.61E-06Fluoranthene Yes 2.94E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-32.06E-09 9.02E-09Fluorene Yes 2.75E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.92E-09 8.42E-09Hexane Yes 1.76E-03 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-03 5.41E-03Indeno(1,2,3-cd)pyrene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Manganese Yes 3.73E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-42.61E-07 1.14E-06MercuryYes 2.55E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.78E-07 7.82E-07Naphthalene Yes 5.98E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-34.19E-07 1.83E-06Nickel Yes 2.06E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.44E-06 6.31E-06Phenanathrene Yes 1.67E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.17E-08 5.11E-08Pyrene Yes 4.90E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-33.43E-09 1.50E-08Selenium Yes 2.35E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.65E-08 7.21E-08Toluene Yes 3.33E-06AP-42 Nat. Gas Comb. (7/98), Table 1.4-32.33E-06 1.02E-05Total (TPY)= 0.006EquipmentHeat Input(MMBtu/hr)Hours of Operation(hrs/yr)Treater Burner0.7 8760TOTAL 0.7Notes:*Regulated under Section 112(b) for Clean Air Act.Example CalculationEstimated Uncontrolled Emissions (lbs/hr) = Emission Factor (lbs/MMBtu) x Heat Input Rate (MMBtu/hr)Estimated Uncontrolled Emissions (tons/yr) = Estimated Uncontrolled Emissions (lbs/hr) x Hours of Operation / 2000Estimated Uncontrolled Emissions(tons/yr)**Emission factors taken from AP-42, Chapter 1 - External Combustion Sources, Table 1.4-3 - Emission Factors for Speciated Organic Compounds from Natural Gas Combustion andTable 1.4-4 - Emission Factors for Metals from Natural Gas Combustion.PollutantHAP*Yes/NoEmission Factor(lb/MMBtu)**Emission Factor SourceEstimated Uncontrolled Emissions(lb/hr)6Attachment 2 - Calculations for EPA Air Registration.xlsx, Treater Burner - HAPs9/30/2011Truck Loading Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HCargo Carrier Mode of Operation S FactorSubmerged loading of a clean cargotank0.50Submerged loading: dedicatednormal service0.60Submerged loading: dedicated vaporbalance service1.00Table 2 - Vapor Pressure and Molecular Weight Values40 50 60 70 80 90 100Crude Oil RVP 5 50 4.5 7.1 1.8 2.3 2.8 3.4 4.0 4.8 5.7Values based on AP-42, Chapter 7 - Liquid Storage Tanks, Table 7.1-2 - Properties (Mv, PVA, WL) of Selected Petroleum Liquids.Constant Saturation Factor (S)Vapor Pressure (P)(psi)MolecularWeight (M)(lb/lb-mole)Temperature (T)(°R)Loading Loss(lb/1,000 gal)12.46 0.60 1.90 44.11 501 1.25Loading Loss(lb/1,000 gal)Truck Load Rate (bbl/hr)Truck Load Time(hrs)gal/bbl Annual bbl/yrPotentialUncontrolled VOCEmissions(lbs/hr)PotentialUncontrolled VOCEmissions(tons/yr)PotentialUncontrolled C3+VOC Emissions*(tons/yr)1.25 200.00 1.00 42.00 511000.00 10.50 13.41 10.38Notes:*VOC weight fraction of the tank vapor gas (C3+). If site specific data is not available, use the Bakken default value of 79.8%.UncontrolledPotential VOCEmissions(tons/yr)Control (%) 1 - Control (%)ControlledPotential VOCEmissions(tons/yr)10.38 0.00 1.00 10.38Notes:Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirementsExample CalculationsLoading Loss (lb/1,000 gal) = Constant * Saturation Factor * Vapor Pressure * (Molecular Weight / Temperature)Potential Emissions (lbs/hr) = Loading Loss / 1000 * (Truck Load Rate / Truck Load Time) * gal/bblUncontrolled Potential Emissions (tons/yr) = (Loading Loss / 1000) * Annual bbl/yr * gal/bbl / 2000Controlled Potential Emissions (tons/yr) = Uncontrolled Emissions * 1 - Control EfficiencyAP-42 EquationLL = 12.46 x (S x P x M)/TLL = Loading loss, pound per 1,000 gallons of liquid loaded (lb/1000 gal)S = Saturation factor (AP-42 Table 5.2-1)P = True vapor pressure of liquid loaded (psia) (AP-42 Table 7.1-2)M = Molecular weight of tank vapors (lb/lb-mol) (AP-42 Table 7.1-2)T = Temperature of bulk liquid loaded (°R) (°R = °F + 460)Table 1 - Saturation Factor VariableTank Trucks and RailTank CarsFactors based on AP-42, Section 5.2 - Transportation and Marketing of PetroleumLiquids, Table 5.2-1 - Saturation (S) Factors for Calculating Petroleum LiquidLoading Losses.True Vapor Pressure(psi) at various temperatures in °FPetroleum LiquidVapor MW at 60°F(lb/lb-mole)Condensed VaporDensityat 60°F (lb/gal)Liquid Density at60°F (lb/gal)6Attachment 2 - Calculations for EPA Air Registration.xlsx, Truck Loading9/30/2011Reciprocating Internal Combustion Gasoline Engines (RICE) Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEngine # Maximum HPHours ofOperation***NOxDRE (%)**NOx Emission Factor(g/HP-HR)*CO DRE (%)**CO Emission Factor(g/HP-HR)*VOC DRE (%)**VOC Emission Factor(g/HP-HR)*PM10EmissionFactor(g/HP-HR)*SO2EmissionFactor(g/HP-HR)*CO2EmissionFactor(g/HP-HR)*Engine #1 8.00 120.00 0% 4.99 0% 3.16 0% 6.80 0.33 0.27 489.89Engine #2 8.00 120.00 0% 4.99 0% 3.16 0% 6.80 0.33 0.27 489.89Engine #3 100.00 0 90% 10.00 75% 5.00 70% 4.00 0.33 0.27 489.89Engine #4 100.00 0 90% 10.00 75% 5.00 70% 4.00 0.33 0.27 489.89Notes:**Control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.***Engine is assumed to operate 8,760 hours per year.Uncontrolled EmissionsPollutantEngine #1 PotentialEmissions (lbs/hr)Engine #1 PotentialEmissions (tons/yr)Engine #2 PotentialEmissions (lbs/hr)Engine #2 PotentialEmissions (tons/yr)Engine #3 PotentialEmissions (lbs/hr)Engine #3 PotentialEmissions (tons/yr)Engine #4 PotentialEmissions (lbs/hr)Engine #4 PotentialEmissions (tons/yr)Total PotentialUncontrolledEmissions (lbs/hr)Total PotentialUncontrolledEmissions(tons/yr)NOx 0.09 0.01 0.09 0.01 2.20 0.00 2.20 0.00 4.59 0.01CO0.06 0.00 0.06 0.00 1.10 0.00 1.10 0.00 2.32 0.01VOC0.12 0.01 0.12 0.01 0.88 0.00 0.88 0.00 2.00 0.01PM100.01 0.00 0.01 0.00 0.07 0.00 0.07 0.00 0.16 0.00SO20.005 0.00 0.00 0.00 0.06 0.00 0.06 0.00 0.13 0.00CO28.64 0.52 8.64 0.52 108.00 0.00 108.00 0.00 233.28 1.04Controlled EmissionsPollutantEngine #1 PotentialEmissions (lbs/hr)Engine #1 PotentialEmissions (tons/yr)Engine #2 PotentialEmissions (lbs/hr)Engine #2 PotentialEmissions (tons/yr)Engine #3 PotentialEmissions (lbs/hr)Engine #3 PotentialEmissions (tons/yr)Engine #4 PotentialEmissions (lbs/hr)Engine #4 PotentialEmissions (tons/yr)Total PotentialControlledEmissions (lbs/hr)Total PotentialControlledEmissions(tons/yr)NOx 0.09 0.01 0.09 0.01 0.22 0.00 0.22 0.00 0.62 0.01CO0.06 0.00 0.06 0.00 0.28 0.00 0.28 0.00 0.66 0.01VOC0.12 0.01 0.12 0.01 0.26 0.00 0.26 0.00 0.77 0.01PM100.01 0.00 0.01 0.00 0.07 0.00 0.07 0.00 0.16 0.00SO20.005 0.00 0.00 0.00 0.06 0.00 0.06 0.00 0.13 0.00CO28.640 0.52 8.64 0.52 108.00 0.00 108.00 0.00 233.28 1.04Notes:Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Total Combined HP:216.00Total Hours of Operation:240.00Example CalculationsPotential Controlled Emissions (lbs/hr) = HP x Emission Factor (g/HP-hr) / Conversion Factor x 1 - Control EfficiencyPotential Controlled Emissions (tons/yr) = Potential Emissions (lbs/hr) * Hours of Operation / 2000*Emission factors for NOx, CO and VOC are based on Manufacturer's emission factor, actual test results, or AP-42 factor in grams per horsepower hour (g/hp-hr).Emission factors for PM10,SO2,and CO2are taken from AP-42, Table 3.3-1 - Emission Factors for Uncontrolled Gasoline and Diesel Industrial Engines. Factors are converted to g/hp-hr from lb/hphr.6Attachment 2 - Calculations for EPA Air Registration.xlsx, RICE Engines9/30/2011Pneumatic Pumps Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HPneumatic SourceConsumptionRate* (scf/min)Supply GasMolecularWeight**(lb/lb-mole)VOC wt Fraction(%)HAP wt Fraction(%)Hours ofOperation***(hrs/yr)ControlEfficiency (%)Number ofPumpsPotentialUncontrolledVOC Emissions(lbs/hr)PotentialUncontrolled VOCEmissions(tons/yr)PotentialControlled VOCEmissions(tons/yr)PotentialUncontrolledHAP Emissions(lbs/hr)PotentialUncontrolled HAPEmissions(tons/yr)Potential ControlledHAP Emissions(tons/yr)0.50 28.46 41.42% 3.50% 4380 1.00 2.0 0.93 4.1 4.1 0.08 0.3 0.3Notes:*PSCR = Pneumatic Source Consumption Rate (scf/min), as per manufacturers literature.**Gas MW = Supply Gas Average Molecular Weight (lb/lb-mole).***Hours the pump is in operation annually. For winter months only, please enter 4380 hours.Example CalculationsCalculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Potential Controlled Emissions (lb/hr) = PSCR (scf/min) x (60 min/1hr) x (1/379 scf/lb-mole) x Supply Gas MW x VOC wt. Fractionx Control EfficiencyPotential Controlled Emissions (tons/yr) = lb/hr VOC x Hours of Operation x 1 ton/2000 x Number of Pumps6Attachment 2 - Calculations for EPA Air Registration.xlsx, Pneumatic Pump9/30/2011Pneumatic Controllers Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HPneumatic SourceConsumptionRate* (scf/hr)Supply GasMolecularWeight**(lb/lb-mole)VOC wt Fraction(%)HAP wt Fraction(%)Hours ofOperation***(hrs/yr)Number ofControllersPotential VOCEmissions(lbs/hr)Potential VOCEmissions(tons/yr)Potential HAPEmissions(lbs/hr)Potential HAPEmissions(tons/yr)17.40 28.46 41.42% 3.50% 4380 4.0 0.54 4.7 0.05 0.4Notes:*PSCR = Pneumatic Source Consumption Rate (scf/min), as per manufacturers literature.**Gas MW = Supply Gas Average Molecular Weight (lb/lb-mole).***Hours the pump is in operation annually. For winter months only, please enter 4380 hours.Example CalculationsCalculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Potential Emissions (lb/hr) = PSCR (scf/min) x (60 min/1hr) x (1/379 scf/lb-mole) x Supply Gas MW x VOC wt. FractionPotential Emissions (tons/yr) = lb/hr VOC x Hours of Operation x 1 ton/2000 x Number of Pumps6Attachment 2 - Calculations for EPA Air Registration.xlsx, Pneumatic Controller9/30/2011

# Tank Flare Combustion - Greenhouse Gases Emission Summary

US EPA - Region 8 Air Program

Federal New Source Review Program in Indian Country

Marathon Oil Compan y

Maggie Old Dog USA 24-19H

CO2 from

Component "I" Gas Burned

(scf) G as M o l

Fraction

of "I" M o l

Factor

of "I" Conversion

Factor @100%

Tonnes

CO 2 

# Flare @ 98%,

tonnes

CH4 

# 50,032,010 0.07242 1 0.0000526 190.6 187

C2H6 50,032,010 0.24148 2 0.0000526 1271.0 1,246

C3H8 50,032,010 0.33425 3 0.0000526 2638.9 2,586

Iso-C4H10 50,032,010 0.04619 4 0.0000526 486.2 477

Nor-C4H10 50,032,010 0.15573 4 0.0000526 1639.3 1,607

Iso-C5H12 50,032,010 0.02605 5 0.0000526 342.8 336

Nor-C5H12 50,032,010 0.03643 5 0.0000526 479.4 470

C6 and + 50,032,010 0.03406 6 0.0000526 537.8 527

CO2 50,032,010 0.00285 1 0.0000526 7.5 8

0.94946 tonnes CO2 from combustion 7,442

uncombusted methane as CO2e 29

total tankflare GHG as CO2e, tonnes 7,471

tpy 8,237 

# Tank Flare Gas GHG EmissionsNatural Gas Combustion (Treater Burner) - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEmission Factor Tablevalue custom default units value custom default units value custom default units value custom default unitsNatural Gas Fossil-gaseous 0.001028 1.028E-03 MMBtu/scf 53.02 53.02 kg/MMBtu 0.001 1.0E-03 kg/MMBtu 0.0001 1.0E-04 kg/MMBtuNotes:a) Default values for natural gas were obtained from the EPA Greenhouse Gas Reporting Rule (10/30/2009) Tables C-1 and C-2.b) Please convert any custom values to the specified default units.Annual GHG Calculation(By GHG Rule Eq. C-2a and C-2b)Fuel Use(MMBtu/hr)Fuel Use(MMBtu/yr)Calculation Tier(a)0.70 6,132 Tier 1CO2CH4N2OTOTAL53.02 0.001 0.0001 --325 0.006 0.0006 --1 21 310 --325 0.13 0.19 325358 0.14 0.21 359Notes:Color Key:Required DataOptional Data (Provide if Available)CH4Emission Factor N2O Emission FactorEstimated GHG Emissions (tons CO2e)b) Emission factors (EF) for natural gas were obtained from Tables C-1 and C-2 of the EPA Greenhouse GasReporting Rule (40 CFR 98).c) Global warming potentials (GWP) were obtained from Table A-1 of the EPA Greenhouse Gas Reporting Rule (40CFR 98).Fuel Fuel ClassificationHigher Heating ValueCO2Emission FactorParameterEF(b)(kg/MMBtu)Estimated GHG Emissions (metric tons)GWP(c)(kg CO2e/kg)Estimated GHG Emissions (metric tons CO2e)a) The default HHV value from Table C-1 of the EPA Greenhouse Gas Reporting Rule is substituted when no actualHHV data from fuel sampling is available. Use of the default HHV value constitutes the Tier 1 calculation methodwhile use of HHV values obtained from fuel sampling constitutes Tier 2.6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Natural Gas9/30/2011Natural Gas Pneumatic Device Venting - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEmission Factor Table*PopulationEmission Factors -All Components,Gas ServiceValve Connector Open-Ended Line Pressure Relief ValveLow Continuous BleedPneumatic DeviceVents**High Continuous BleedPneumatic DeviceVents**Intermittent BleedPneumatic DeviceVents**Pneumatic Pumps**Emission Factor(scf/hour/component)0.123 0.017 0.032 0.196 1.8 48.1 17.4 13.3Notes:*Default values were obtained from the EPA Greenhouse Gas Reporting Rule Table W-1A - Default Whole Gas Emission Factors for Onshore Petroleum and Natural Gas Production (Western U.S.)**Emission Factor is in units of scf/hour/device or scf/hour/pumpAnnual GHG CalculationCount - ContinuousHigh BleedEF - Continuous HighBleed(scf/hour/device)Count - ContinuousLow BleedEF - Continuous LowBleed(scf/hour/device)Count - IntermittentBleedEF - IntermittentBleed(scf/hour/device)Concentration of CH4inProduced Natural Gas(GHGi)Concentration of CO2inProduced Natural Gas(GHGi)Conversion (Convi)from standard cubicfeet CH4tometric tons CO2eConversion (Convi)from standard cubicfeet CO2tometric tons CO2eGlobal WarmingPotential (GWP) - CH4(kg CO2e/kg)2.0 48.1 0.0 1.8 0.0 17.4 47% 1% 0.000410 0.00005357 21Emissions in Metric Tons CO2e (GHG Rule Eq. W-1)ContinuousHigh Bleed -CH4Emissions(metric tons CO2e)ContinuousHigh Bleed -CO2Emissions(metric tons CO2e)ContinuousLow Bleed -CH4Emissions (metrictons CO2e)ContinuousLow Bleed -CO2Emissions (metrictons CO2e)Intermittent Bleed -CH4Emissions(metric tons CO2e)Intermittent Bleed -CO2Emissions (metrictons CO2e)TotalCH4Emissions(metric tons CO2e)TotalCO2Emissions(metric tons CO2e)TotalGHG Emissions(metric tons CO2e)163.22 0.50 0.00 0.00 0.00 0.00 163.22 0.50 163.72Emissions in Metric Tons CH4ContinuousHigh Bleed(metric tons CH4)ContinuousLow Bleed -(metric tons CH4)Intermittent Bleed -(metric tons CH4)TotalCH4Emissions (metrictons CH4)7.77 0.00 0.00 7.77Notes:a) Calculation for Natural Gas Pneumatic Device Venting found in 98.233(a) Equation W-1 -Masss,I = Count * EF * GHGi * Convi * 24 *365Masss,I= Annual total mass GHG emissions in metric tons CO2eCount = Total number of continuous high bleed, continuous low bleed, or intermittent bleed natural gas pneumatic devices of each typeEF = Population emission factorsGHGi= Concentration of GHGi, CH4or CO2in produced natural gas (For facilities in 98.230(a)(3)-(a)(8), GHGi = 1)Convi= Conversion from scf to metric tons CO2e, 0.000410 for CH4or 0.00005357 for CO2b) Global warming potentials (GWP) were obtained from Table A-1 of the EPA Greenhouse Gas Reporting Rule (40 CFR 98).6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Pneumatic Device Venting9/30/2011Natural Gas Pneumatic Pumps - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEmission Factor Table*PopulationEmission Factors -All Components,Gas ServicePneumatic Pumps**Emission Factor(scf/hour/component)13.3Notes:*Default values were obtained from the EPA Greenhouse Gas Reporting Rule Table W-1A - Default Whole Gas Emission Factors for Onshore Petroleum and Natural**Emission Factor is in units of scf/hour/device or scf/hour/pumpAnnual GHG CalculationCount - PneumaticPumpsEF - PneumaticPumps(scf/hour/device)Concentration of CH4in Produced NaturalGas(GHGi)Concentration of CO2in Produced NaturalGas(GHGi)Conversion (Convi)from standard cubicfeet CH4tometric tons CO2eConversion (Convi)from standard cubicfeet CO2tometric tons CO2eGlobal WarmingPotential (GWP) - CH4(kg CO2e/kg)2.0 13.3 47.2% 1.115% 0.000410 0.00005357 21Emissions in Metric Tons CO2e (GHG Rule Eq. W-1)Pneumatic PumpsCH4Emissions(metric tons CH4)Pneumatic PumpsCH4Emissions(metric tons CO2e)Pneumatic PumpsCO2Emissions (metrictons CO2e)TotalGHG Emissions(metric tons CO2e)2.15 45.13 0.14 45.27Notes:a) Calculation for Natural Gas Pneumatic Device Venting found in 98.233(a) Equation W-2 -Masss,I = Count * EF * GHGi * Convi * 24 *365Masss,I= Annual total mass GHG emissions in metric tons CO2eCount = Total number of natural gas pneumatic pumpsEF = Population emission factorsGHGi= Concentration of GHGi, CH4or CO2in produced natural gas (For facilities in 98.230(a)(3)-(a)(8), GHGi = 1)Convi= Conversion from scf to metric tons CO2e, 0.000410 for CH4or 0.00005357 for CO2b) Global warming potentials (GWP) were obtained from Table A-1 of the EPA Greenhouse Gas Reporting Rule (40 CFR 98).6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Pneumatic Pumps9/30/2011Gas Production (Western U.S.).6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Pneumatic Pumps9/30/2011Associated Gas Venting and Flaring - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HAnnual Volumetric Natural Gas Emissions (cubic feet) (GHG Rule Eq. W-18)Gas to Oil Ratio (GOR)(cubic feet ofgas/barrel of oil)Volume of Oil Produced(V)(barrels/year)Annual VolumetricNatural Gas Emissions(Ea,n) (cubic feet)Percent of AnnualVolumetric NaturalGas Not Flared (%)Annual VolumetricNatural Gas Emissions -Not Flared (cubic feet)1,000.00511,000.00511,000,000.000% 0.00Calculation for Venting Emissions found in 98.233(m) Equation W-18Ea,n= GOR * VNatural Gas Volumetric Emissions - Standard Conditions (GHG Rule Eq. W-33)Natural Gas VolumetricEmissions at ActualConditions (Ea,n) (cubicfeet)Temperature atStandard Conditions (Ts)(°F)Temperature at ActualEmission Conditions(Ta) (°F)Absolute Pressure atStandard Conditions(Ps) (psia)Absolute Pressure atActual Conditions(Pa) (psia)Natural Gas VolumetricEmissions at STP(Es,n) (cubic feet)0.00 60.00 60.00 14.70 13.60 0.00Calculation for Natural Gas Volumetric Emissions - Standard Conditions found in 98.233(t) Equation W-33GHG Volumetric Emissions (cubic feet) (GHG Rule Eq. W-35)Natural Gas VolumetricEmissions at ActualConditions (Es,n) (cubicfeet)Mole Fraction (Mi) - CH4Mole Fraction (Mi) -CO2CH4VolumetricEmissions at STP (Es,i)(cubic feet)CO2Volumetric Emissionsat STP (Es,i)(cubic feet)0.00 0.47 0.01 0.00 0.00Calculation for GHG Volumetric Emissions found in 98.233(u) Equation W-35Es,i= Es,n* MiGHG Mass Emissions (metric tons CO2e) (GHG Rule Eq. W-36)CH4VolumetricEmissions at STP (Es,i)(cubic feet)CO2VolumetricEmissions at STP (Es,i)(cubic feet)Density (Pi) of CO2Density (Pi) of CH4Global WarmingPotential (GWP) of CO2(kg CO2e/kg)Global Warming Potential(GWP) of CH4(kg CO2e/kg)Mass Emissions atStandard Conditions(Massi) - CO2(metric tons CO2e)Mass Emissions atStandard Conditions(Massi) - CH4(metric tons CO2e)Mass Emissions at StandardConditions (Massi) - Total(metric tons CO2e)Mass Emissions atStandard Conditions(Massi) - CH4(metric tons CH4)0.00 0.00 0.0538 0.0196 1 21 0.00E+00 0.00E+00 0.00E+00 0.00E+00Calculate GHG mass emissions in CO2e at standard conditions by converting the GHG volumetric emissions into mass emissionsCalculation for GHG Mass Emissions found in 98.233(v) Equation W-36Masss,i= Es,i* Pi* GWP * 10-3*Density was assumed to be at standard conditions, 68°F and 14.7 psia.Es,i = GHGi (either CH4 or CO2) volumetric emissions at standard conditions in cubic feetEs,n = Natural gas volumetric emissions at standard conditions in cubic feetMi = Mole fraction of GHGi in the natural gas. 98.233(u)(2) - Annual average mole fraction for each facility as specified in 98.233(u)(2)(i) - GHG mole fractionin produced natural gas for onshore petroleum and natural gas production facilities. If you have a continuous gas compositionanalyzer for produced naturalgas, you must use these values for determining the mole fraction. If you do not have a continuous gas composition analyzer, then you must use your mostrecent gas composition based on available sample analysis of the field.Masss,i= GHGi(either CH4or CO2) mass emissions at standard conditions in metric tons CO2eEs,i= GHGi(either CH4 or CO2) volumetric emissions at standard conditions in cubic feetPi= Density of GHGi. Use 0.0538 kg/ft3for CO2and N2O, and 0.0196 kg/ft3for CH4at 68°F and 14.7 psia or 0.0530 kg/ft3for CO2and N2O, and 0.0193 kg/ft3for CH4at 60°F and 14.7 psia.GWP= Global warming potential, 1 for CO2, 21 for CH4, and 310 for N2OEa,n= Annual volumetric natural gas emissions from associated gas venting, in cubic feetGOR= Gas to oil ratio in cubic feet of gas per barrel of oil; oil here refers to hydrocarbon liquids produced of all API gravitiesV= Volume of oil produced in barrels in the calendar year during which associated gas was vented or flaredEs,n= Ea,n* (459.67 + Ts) * Pa(459.67 + Ta) * PsEs,n= Natural gas volumetric emissions at standard temperature and pressure (STP) conditions in cubic feetEa,n= Natural Gas Volumetric Emissions at Actual Conditions in Cubic FeetTs= Temperature at standard conditions (°F)Ta= Temperature at actual emission conditions (°F)Ps= Absolute pressure at standard conditions (psia)Pa= Absolute pressure at actual conditions (psia)6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Gas Venting (Unflared)9/30/2011Flare Stack Emissions - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HGHG Volumetric Emissions at Actual Conditions (cubic feet)Annual Un-Combusted CH4Emissions (cubic feet) (GHG Rule Eq. W-19)Volume of Gas Flared(Va)(cubic feet/yr)Fraction of GasCombusted byBurning Flare (n) (%)Mole Fraction of CH4inFlared Gas (XCH4)AnnualUn-Combusted CH4Emissions (Ea,CH4)(cubic feet)511,000,000.00 98% 0.47 4,827,846.2400Calculation for Flare Stack Emissions - Annual Un-Combusted CH4 Emissions found in 98.233(n) Equation W-19Ea,CH4(un-combusted) = Va* (1 - n) * XCH4Annual Un-Combusted CO2Emissions (cubic feet) (GHG Rule Eq. W-20)Volume of Gas Flared(Va)(cubic feet/yr)Mole Fraction of CO2in Flared Gas (XCO2)AnnualUn-Combusted CO2Emissions (Ea,CO2)(cubic feet)511,000,000.00 0.01 5,699,694.00Calculation for Flare Stack Emissions - Annual Un-Combusted CO2 Emissions found in 98.233(n) Equation W-20Ea,CO2(un-combusted) = Va* XCO2Annual Combusted CO2Emissions (cubic feet) (GHG Rule Eq. W-21)Volume of Gas Flared(Va)(cubic feet/yr)Fraction of GasCombusted byBurning Flare (n)(%)AnnualCombusted CO2Emissions (Ea,CO2)(cubic feet)511,000,000.00 98% 896,934,538.50Calculation for Flare Stack Emissions - Annual Combusted CO2 Emissions found in 98.233(n) Equation W-21Ea,CO2(combusted) =∑jn * Va* Yj* RjEa,CH4(un-combusted)= Contribution of annual un-combusted CH4emissions from flare stack in cubic feet, under actual conditionsVa= Volume of gas sent to flare in cubic feet, during the yearn= Fraction of gas combusted by a burning flare (default is 0.98). For gas sent to an unlit flare, n is zeroXCH4= Mole fraction of CH4in gas to the flareEa,CO2(un-combusted)= Contribution of annual un-combusted CO2emissions from flare stack in cubic feet, under actual conditionsVa= Volume of gas sent to flare in cubic feet, during the yearXCO2= Mole fraction of CO2in gas to the flareEa,CO2(combusted)= Contribution of annual combusted CO2emissions from flare stack in cubic feet, under actual conditionsVa= Volume of gas sent to flare in cubic feet, during the yearn= Fraction of gas combusted by a burning flare (default is 0.98). For gas sent to an unlit flare, n is zeroYj= Mole fraction of gas hydrocarbon constituents j (such as methane, ethane, propane, butane, and pentanes-plus)Rj= Number of carbon atoms in the gas hydrocarbon constituents j: 1 for methane, 2 for ethane, 3 for propane, 4 for butane, and5 for pentane plus6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Flare Stacks9/30/2011Flare Stack Emissions - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HNatural Gas Volumetric Emissions - Standard Conditions (GHG Rule Eq. W-33)Natural Gas VolumetricEmissions at ActualConditions (Ea,n) (cubicfeet)Temperature atStandard Conditions(Ts) (°F)Temperature at ActualEmission Conditions (Ta)(°F)Absolute Pressure atStandard Conditions (Ps)(psia)Absolute Pressure atActual Conditions (Pa)(psia)Natural Gas VolumetricEmissions at STP (Es,n)(cubic feet)511,000,000.00 60.00 60.00 14.70 13.60 472,761,904.76Calculation for Natural Gas Volumetric Emissions - Standard Conditions found in 98.233(t) Equation W-33GHG Mass Emissions (metric tons CO2e) (GHG Rule Eq. W-36)CH4VolumetricEmissions at STP (Es,i)(cubic feet)CO2VolumetricEmissions at STP (Es,i)(cubic feet)Density (Pi) of CO2Density (Pi) of CH4Global Warming Potential(GWP) of CO2(kg CO2e/kg)Global Warming Potential(GWP) of CH4(kg CO2e/kg)Mass Emissions at StandardConditions (Massi) - CO2(metric tons CO2e)Mass Emissions at StandardConditions (Massi) - CH4(metric tons CO2e)Mass Emissions at StandardConditions (Massi) - Total(metric tons CO2e)Mass Emissions atStandard Conditions(Massi) - CH4(metric tons CH4)4,827,846.24 902,634,232.50 0.0538 0.0196 1 21 4.86E+04 1.99E+03 5.05E+04 9.46E+01Calculate GHG mass emissions in CO2e at standard conditions by converting the GHG volumetric emissions into mass emissionsCalculation for GHG Mass Emissions found in 98.233(v) Equation W-36Masss,i= Es,i* Pi* GWP * 10-3*Potential N2O emissions from fuel combustion in the flare are assumed to be negligible.**Density was assumed to be at standard conditions, 68°F and 14.7 psia.Subpart W Equation W-40 Treater Flare Negligibility CheckHHV, mmBtu/scf (eq. W-40) 1.235E-03EF, kg N2O/mmBtu 1.00E-04convert kg to metric tons1.00E-03combusted gas volume, scf/yr511,000,000N2O, metric tons 6.3E-02N2O emissions are negligibleEs,n= Ea,n* (459.67 + Ts) * Pa(459.67 + Ta) * PsEs,n= Natural gas volumetric emissions at standard temperature and pressure (STP) conditions in cubic feetEa,n= Natural Gas Volumetric Emissions at Actual Conditions in Cubic FeetTs= Temperature at standard conditions (°F)Ta= Temperature at actual emission conditions (°F)Ps= Absolute pressure at standard conditions (psia)Pa= Absolute pressure at actual conditions (psia)Masss,i= GHGi(either CH4or CO2) mass emissions at standard conditions in metric tons CO2eEs,i= GHGi(either CH4 or CO2) volumetric emissions at standard conditions in cubic feetPi= Density of GHGi. Use 0.0538 kg/ft3for CO2and N2O, and 0.0196 kg/ft3for CH4at 68°F and 14.7 psia or 0.0530 kg/ft3for CO2and N2O,and 0.0193 kg/ft3for CH4at 60°F and 14.7 psia.GWP= Global warming potential, 1 for CO2, 21 for CH4, and 310 for N2O6Attachment 2 - Calculations for EPA Air Registration.xlsx, GHG - Flare Stacks9/30/2011Bakken Pool Oil and Gas Production FacilitiesAir Pollution Control Permitting & Compliance Guidance - May 2, 2011North Dakota Department of Health - Division of Air QualityDefault FactorsOil/Condensate Tank DataVapor Recovery Unitor Oil StabilizerEnclosed SmokelessCombustorUtility Flare or Other 98% DREDeviceGround Pit Flare or Other 90% DRE Device97.91 2000 45.19 79.8 2.26 99 98 98 90Control RequirementsIf first date of production occurred after June 1, 2011, tank emissions must be controlled by a ground it flare or other control device that achieves at least 90% DRE for VOCs upon startup of the facility.Facilities must calculate VOC PTE within 90 days after the first day of production.If PTE for VOC emissions is < 20 tpy, then a minimum of a ground pit flare (90% DRE) is required.If PTE for VOC emissions is > 20 tpy, then a control device that achieves at least 98% DRE must be installed and operated.Treater Gas DataEnclosed SmokelessCombustorUtility Flare or Other 98%DRE DeviceGround Pit Flare or Other90% DRE DeviceConnected to Sales Line98 98 90 100Control RequirementsTreater gas must be routed to a gas gathering pipeline as soon as practicable in accordance with North Dakota Industrial Commission Requirements.When a pipeline is not available, treater gas is required to be routed to a control system or device (appropriate devices are included in the table above).Treater Burner DataNOx CO VOCHAPS8,760100 84 5.5 1.89*Taken from AP-42, Tables 1.4-1, 1.4-2 and 1.4-3 - Emission Factors from Natural Gas Consumption. Based on average heating value of 1020 Btu/scf of natural gas.Truck Loading DataSubmerged Loading of aClean Cargo TankSubmerged Loading:Dedicated Normal ServiceSubmerged Loading:Dedicated VaporBalance ServiceOil is Hauled by Truck Oil is Sold through LACT 0.5 0.6 1Refer to Table 2 onTruck Loading tabRefer to Table 2 onTruck Loading tabIf no specific data, useestimated average annualtemperatureEmissions calculated using formula provided in AP-42.Saturation factors taken from AP-42, Table 5.2-1 - Saturation (S) Factors for Calculating Petroleum Liquid Loading Loss.P and M values taken from Table 7.1-2 - Properties of Selected Petroleum Liquids.Control RequirementsBakken Pool O&G production facilities are not required to route emissions displaced from truck loading activities to a controlsystem or device due to safety concerns.However, the owner/operator shall follow any operating and/or construction requirements established in Chapters 33-15-07 and 33-15-20 of the North Dakota Air Pollution Control Rules.Destruction Devices and Efficiency (%)Default Bakken EF(scf/bbl)Lower Heating Value ofTank Vapors(Btu/scf)Molecular Weight of TankVapors(lb/lb-mole)VOC Weight Fraction ofTank Vapor Gas (C3+) (%)HAP Weight Fractionof Tank Vapor Gas (%)Destruction Devices and Efficiency (%)Sales MethodMode of Operation and Appropriate Saturation FactorMolecular Weight ofTank Vapors(lb/lb-mole)Vapor Pressure ofLiquid Loaded(psia)Temperature of Bulk LiquidLoaded (°F)Hours of OperationNatural Gas Emission Factors* (lb/MMscf)6Attachment 2 - Calculations for EPA Air Registration.xlsx, NDDoH Default Factors 28 of 369/30/2011Bakken Pool Oil and Gas Production FacilitiesAir Pollution Control Permitting & Compliance Guidance - May 2, 2011North Dakota Department of Health - Division of Air QualityDefault FactorsPneumatic Pumps DataRouted Exhaust Back intoClosed Loop SystemRouted Exhaust to aCombustion Device4,380 100 98Control RequirementsBakken Pool O&G production facilities are required to control pneumatic pumps that use natural gas as the motive gas, if the PTE of VOCs from the pneumatic pump is > 5 tpy per pump.Pneumatic Controllers DataThere are not default factors for pneumatic controllers. Emissions are calculated based on the following: number of controllers, gas usage or bleed rate (scf/hr), VOC/HAP weight fraction, molecular weight and hours of operation.Control RequirementsBakken Pool O&G production facilities are not required to install add-on controls for emissions from these types of devices.Glycol Dehydrator DataVOC Emissions (tpy) HAP Emissions (tpy)0 0Use emissions calculated in GRI-GLYCalc V4 software; if no Glycol Dehydrator is installed, enter 0.RICE Engines DataHours of OperationNOx AP-42Emissions Factor(g/hp-hr)CO AP-42Emissions Factor(g/hp-hr)VOC AP-42Emissions Factor(g/hp-hr)NOx Control EfficiencyCO ControlEfficiencyVOC Control Efficiency8,760Manufacturer data, actualtest results orAP-42 emission factorsManufacturer data, actualtest results orAP-42 emission factorsManufacturer data, actualtest results orAP-42 emission factorsManufacturer data oractual test resultsManufacturer data oractual test resultsManufacturer data oractual test resultsWhile emission factors from actual stack testing, manufacturer's engine data, and AP-42 are acceptable, actual test data is usually the most accurate and preferred method.Control RequirementsNDDoH does not require any specific air pollution control equipment; however, the RICE must be in compliance with all State andFederal Rules and Regulations.See the Federal Rules and Regulations tab for specifics regarding applicable Federal Rules.Annual Hours of Operation -Winter Months OnlyControl Devices and Efficiency (%)6Attachment 2 - Calculations for EPA Air Registration.xlsx, NDDoH Default Factors 29 of 369/30/2011US EPAAP 42, Compilation of Air Pollutant Emission FactorsApplicable TablesOil/Condensate Tank and Treater Flare13.5-1 - Emission Factors for Flare OperationsTotal Hydrocarbonsb0.14Carbon Monoxide 0.37Nitrogen Oxides 0.068Sootc0 - 274bMeasured as methane equivalent.Treater Burner DataTable 1.4-1 - Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas CombustionCombustor Type(MMBtu/hr Heat Input)NOxEmission Factor(lb/106scf)CO Emission Factor(lb/106scf)Uncontrolled (Pre-NSPS) 280 84Uncontrolled (Post-NSPS) 190 84Controlled - Low NOxBurners140 84Controlled - Flue Gas Recirculation 100 84Uncontrolled 100 84Controlled - Low NOxBurners50 84Controlled - Low NOxBurner /Flue Gas Recirculation32 84Uncontrolled 170 24Controlled - Flue Gas Recirculation 76 98Uncontrolled 94 40Units are in lb/MMscf of natural gas fired. To convert from lb/106scf to lb/MMBtu, divide by 1,020.ComponentEmission Factor(lb/106Btu)cSoot in concentration values: nonsmoking flares, 0 micrograms per liter (ug/l); lightlysmoking flares, 40 mg/l; average smoking flares, 177 ug/l; and heavy smoking flares, 274ug/l.Large Wall-Fired Boilers (>100)Small Boilers (< 100)Tangential-Fired Boilers (All Sizes)Residential Furnaces (< 0.3)6Attachment 2 - Calculations for EPA Air Registration.xlsx, AP-42 Tables 30 of 369/30/2011US EPAAP 42, Compilation of Air Pollutant Emission FactorsApplicable TablesTable 1.4-2 - Emission Factors for Criteria Pollutants and Greenhouse Gases from Natural Gas CombustionPollutantEmission Factor(lb/106scf)CO2120,000Lead0.0005N2O (Uncontrolled)2.2N2O (Controlled - Low NOxBurner)0.64PM (Total)7.6PM (Condensable)5.7PM (Filterable)1.9SO20.6TOC11Methane2.3VOC5.5PM is assumed to be less than 1.0 micrometer in diameter. Therefore, the PM emission factors may be used to estimate PM10and PM2.5.SO2is based on 100% conversion of fuel sulfur to SO2. Assumes sulfur content is natural gas of 2,000 grains/106scf.Table 1.4-3 - Emission Factors for Speciated Organic Compounds from Natural Gas CombustionEmission factors are included in the Natural Gas Combustion calculations.Truck LoadingTable 5.2-1 - Saturation (S) Factors for Calculating Petroleum Liquid Loading LossesCargo Carrier Mode of Operation S FactorSubmerged loading of aclean cargo tank0.50Submerged loading:dedicated normal service0.60Submerged loading:dedicated vapor balanceservice1.00Splash loading of a cleancargo tank1.45Splash loading: dedicatednormal service1.45Splash loading: dedicatedvapor balance service1.00Tank Trucks and Rail Tank Cars6Attachment 2 - Calculations for EPA Air Registration.xlsx, AP-42 Tables 31 of 369/30/2011US EPAAP 42, Compilation of Air Pollutant Emission FactorsApplicable TablesTable 7.1-2 - Properties (MV, PVA, WL) of Selected Petroleum Liquids40°F 50°F 60°F 70°F 80°F 90°F 100°FCrude Oil RVP 5 50 7.1 1.8 2.3 2.8 3.4 4 4.8 5.7Distillate Fuel Oil No. 2 130 7.1 0.0031 0.0045 0.0065 0.0090 0.012 0.016 0.022Gasoline RVP 7 68 5.6 2.3 2.9 3.5 4.3 5.2 6.2 7.4Gasoline RVP 7.8 68 5.6 2.5929 3.2079 3.9363 4.793 5.7937 6.9552 8.2952Gasoline RVP 8.3 68 5.6 2.7888 3.444 4.2188 5.1284 6.1891 7.4184 8.8344Gasoline RVP 10 66 5.6 3.4 4.2 5.2 6.2 7.4 8.8 10.5Gasoline RVP 11.5 65 5.6 4.087 4.9997 6.069 7.3132 8.7519 10.4053 12.2949Gasoline RVP 13 62 5.6 4.7 5.7 6.9 8.3 9.9 11.7 13.8Gasoline RVP 13.5 62 5.6 4.932 6.0054 7.2573 8.7076 10.3774 12.2888 14.4646Gasoline RVP 15.0 60 5.6 5.5802 6.774 8.1621 9.7656 11.6067 13.7085 16.0948Jet Kerosene 130 7.0 0.0041 0.0060 0.0085 0.011 0.015 0.021 0.029Jet Naphtha (JP-4) 80 6.4 0.8 1 1.3 1.6 1.9 2.4 2.7Residual Oil No. 6 190 7.9 0.00002 0.00003 0.00004 0.00006 0.00009 0.00013 0.00019RICE Engines DataTable 3.3-1 - Emission Factors for Uncontrolled Gasoline and Diesel Industrial Engineslb/hp-hr(Power Output)lb/MMBtu(Fuel Input)lb/hp-hr(Power Output)lb/MMBtu(Fuel Input)NOx 0.011 1.63 0.031 4.41CO 6.96E-03 0.99 6.68E-03 0.95SOx 5.91E-04 0.084 2.05E-03 0.29PM10 7.21E-04 0.1 2.20E-03 0.32CO2 1.08 154 1.15 64Aldehydes 4.85E-04 0.07 4.63E-04 0.07TOC - Exhaust 0.015 2.1 2.47E-03 0.35TOC - Evaporative 6.61E-04 0.09 0.00 0.00TOC - Crankcase 4.85E-03 0.69 4.41E-05 0.01TOC - Refueling 1.08E-03 0.15 0.00 0.00Table 3.3-2 - Speciated Organic Compound Emission Factors for Uncontrolled Diesel EnginesEmission factors are included in the RICE calculations.True Vapor Pressure, PVA(psi)PollutantGasoline FuelEmission FactorsDiesel FuelEmission FactorsPetroleum LiquidVapor Molecular Weight @60°F, MV(lb/lb-mole)Liquid Density @60°F, WL(lb/gal)6Attachment 2 - Calculations for EPA Air Registration.xlsx, AP-42 Tables 32 of 369/30/2011Federal Rules and Regulations Applicable to the Oil and Gas IndustryThis regulation document is provided by the North Dakota Department of Health for information purposes only.Please reference the rule for complete applicability and full details.40 CFR Part 60 - New Source Performance Standards (NSPS)Subpart Applicability and Description Subpart Reviewed for ApplicabilitySubpart IIII - Stationary Compression IgnitionInternal Combustion EnginesApplies to any compression ignition internal combustion engine where construction iscommenced after July 11, 2005 where the engine is manufactured after April 1, 2006NASubpart JJJJ - Stationary Spark Ignition InternalCombustion EnginesApplies to any spark ignition internal combustion engine where construction is commencedafter June 12, 2006 where the engine is manufactured:- After July 1, 2007 for engines > 500 hp- After July 1, 2008 for lean-burn engines 500 < hp < 1350- After July 1, 2008 for engines < 500 hp- After January 1, 2009 for emergency enginesonly 8 hp gasoline engine on siteSubpart GG - Stationary Gas TurbinesApplies to all stationary gas turbines with a heat input≥10 MMBtu/hr based on the lowerheating value of the fuel where construction is commenced after October 3, 1997 but beforeFebruary 18, 2005NASubpart KKKK - Stationary Combustion TurbinesApplies to stationary gas turbines with a heat input≥10 MMBtu/hr based on the higherheating value of the fuel where construction, modification or reconstruction is commencedafter February 18, 2005NASubpart Kb - Volatile Organic Liquid (VOL) StorageVessels (Including Petroleum Liquid StorageVessels) for which Construction, Reconstructionor Modification Commenced after July 23, 1984Applies to each storage vessel with a capacity of≥75 m3that is used to store VOL for whichconstruction, reconstruction, or modification commenced after July 23, 1984. Commonexceptions to this rule include:- Does not apply to storage vessels with a capacity > 151 m3storing a liquid with a maximumtrue vapor pressure less than 3.5 kilopascals (kPa)- Does not apply to vessels with a capacity of 75≥m3< 151 storing a liquid with a maximumtrue vapor pressure less than 15.0 kPa- Does not apply to vessels with a design capacity < 1,589.874 m3used for petroleum orcondensate stored, processed or treated prior to custody transferNA - prior to custody transferSubpart Dc - Small Industrial - Commercial -Institutional Steam Generating UnitsApplies to all steam generating units for which construction, modification or reconstruction iscommenced after June 9, 1989 and that has a maximum design capacity of 10≥MMBtu/hr <100NASubpart KKK - Equipment Leaks of VOC fromOnshore Natural Gas Processing PlantsApplies to affected facilities at onshore natural gas processing plants NASubpart LLL - Onshore Natural Gas Processing:SO2EmissionsApplies to each sweetening unit and each sweetening unit followed by a sulfur recovery unitat facilities that process natural gasNAExisting NSPS covers only natural gas processingplants and the proposal would cover additionalemission points including: well completions (andre-completions), compressors, pneumaticcontrollers, storage vessels (condensate andcrude oil tanks.EPA is under a consent decree deadline to takefinal action on these rules by February 28, 2012- Would limit VOC emissions from gas wells as they are being prepared for production, aprocess called "well completion".- Would apply to all hydraulically fractured (fracked) wells, both new wells and existing wellsthat are fracked or refracked to get more gas out of a well.- Would require combination of green completion and flaring for most fractured wells.Achieve 95% VOC reduction and 90% recovery of salable natural gas. Require flaring insituations not meeting criteria for reduced emissions completion where flaring is not ahazard.- Would require VOC reductions from other operations in the oil and gas sector including:-Compressors, which help move natural gas along a pipeline. Centrifugal and reciprocatingcompressors would be required to reduce VOC emissions.-Pneumatic Controllers, which regulate pressure, flow and temperature. Cover unitslocated at gas processing plants and compressor stations.-Storage Tanks, located at wells and other production facilities. Reduce VOC emissions by95%.-Onshore Natural Gas Processing Plants. Strengthen leak detection and repairrequirements of existing NSPS.NA - stil proposedEnginesTurbinesTanksHeatersNatural Gas Processing Plants**Based on the EPA document "Addressing Air Emissions from the Oil and Natural Gas Industry - Overview of EPA's Proposed New Source Performance Standards and NationalEmission Standards for Hazardous Air Pollutants".EPA Review - Natural Gas Processing Plants*6Attachment 2 - Calculations for EPA Air Registration.xlsx, Federal Rules33 of 369/30/2011Federal Rules and Regulations Applicable to the Oil and Gas IndustryThis regulation document is provided by the North Dakota Department of Health for information purposes only.Please reference the rule for complete applicability and full details.40 CFR Part 63 - National Emission Standards for Hazardous Air Pollutants (MACT)Subpart Applicability and Description Subpart Reviewed for ApplicabilitySubpart ZZZZ - Stationary Reciprocating InternalCombustion EnginesApplies to any (new, existing, modified and reconstructed) reciprocating internal combustionengines located at a major source or area source of hazardous air pollutants (HAPs).only 8 hp gasoline engine on siteSubpart HH - Oil and Gas Production FacilitiesApplies to all oil and gas production facilities that are major and area sources of HAPs with thefollowing exceptions:- A facility that exclusively processes, stores or transfers black oil- A major source prior to the point of custody transfer with a facility-wide annual averagenatural gas throughput < 18.4 thousand cubic meters/day and a facility-wide annualhydrocarbon liquid throughput < 37,700 liters/day.The facility will be a synthetic minorsourceSubpart HHH - Natural Gas Transmission andStorage FacilitiesApplies to owners and operators of natural gas transmission and storage facilities thattransport or store natural gas prior to entering the pipeline to a local distribution company orto a final end user and that are major sources of HAP emissions.NAProposal for Air Toxics - Oil and Gas ProductionFacilities and Natural Gas Transmission andStorage Facilities*EPA is under a consent decree deadline to takefinal action on these rules by February 28, 2012Technology Review- No available cost-effective technologies for controlled glycol dehydrators and storage tanksthat could achieve greater reductions that current standards.- Standard for equipment leaks has been made more stringent.Review identified unregulated emission points, and proposal includes provisions to reduceemissions-Glycol Dehydrators- Establish limits for small dehydrators at major sources.-Storage Tanks(Oil and Gas Production Only) - Regulate all crude oil and condensate tanks atmajor sources. Remove throughput, API gravity and gas/oil ratio criteria.Risk Review- Rule proposes to reduce amount of air toxics allowed to be emitted.- Eliminate the 1 tpy benzene compliance option for glycol dehydrators at major sources (Oiland Gas Production and Natural Gas Transmission/Storage).NA - stil proposedEnginesProposal for Air Toxics - Oil and Gas Production Facilities and Natural Gas Transmission and Storage Facilities**Based on the EPA document "Addressing Air Emissions from the Oil and Natural Gas Industry - Overview of EPA's Proposed New Source Performance Standards and NationalEmission Standards for Hazardous Air Pollutants".Oil and Gas Production FacilitiesNatural Gas Transmission and Storage Facilities6Attachment 2 - Calculations for EPA Air Registration.xlsx, Federal Rules34 of 369/30/2011Average Casinghead Gas Analysis DataCompound FuelMW Wt Gross Grosslb/lb-mole lb Btu/scf Btu/scfoxygen n 0.000% 32.00 0.0000 0.00% 0 0.0nitrogen n 2.717% 28.013 0.7611 2.67% 0 0.0H2Sn 0.000% 34.076 0.0000 0.00% 637.1 0.0CO2n 1.115% 44.01 0.4909 1.73% 0 0.0C1 / CH4n 47.239% 16.043 7.5786 26.63% 1010.0 477.1C2 n 26.069% 30.07 7.8389 27.55% 1796.6 468.4C3 y 14.617% 44.10 6.4455 22.65% 2516.1 367.8C4, iso y 1.569% 58.12 0.9122 3.21% 3251.9 51.0C4, n y 3.766% 58.12 2.1888 7.69% 3262.3 122.9C5, iso y 0.594% 72.15 0.4289 1.51% 4000.9 23.8C5, n y 1.131% 72.15 0.8162 2.87% 4008.9 45.3C6+ y 1.182% 84.18 0.9953 3.50% 4755.9 56.2Totals100.00% 28.46 100.00% 1,612.5weight % VOC:41.42%Heating ValueComponent VOCMole2%Wt%

# (If speciated by lab, enter HAPs at bottom of sheet, not lumped with carbon numbers)

(enter composition in %, not mole fraction)

Gas Source: Average from 4 existing locations collected by Comm Engineering



# Sample Date: 05/28/09-06/05/09

Compound Gas



# Correction Mole % Net LHV

Mole % Calculations w/o air Mole Wt Wt Wt% Btu/scf Btu/scf

oxygen 0.000% 0.000% 0.000% 

# 32.00 0.0000 0.00% 

# 0 0.0

nitrogen 5.055% 5.055% 5.055% 

# 28.01 1.4161 3.21% 

# 0 0.0

hydrogen sulfide 0.000% 0.000% 0.000% 

# 34.08 0.0000 0.00% 

# 586.8 0.0

carbon dioxide 0.285% 0.285% 0.285% 

# 44.01 0.125 4 0.28% 

# 0 0.0

methane 7.242% 7.242% 7.242% 

# 16.04 1.1618 2.63% 

# 909.4 65.9

ethane 24.148% 24.148% 24.148% 

# 30.07 7.2613 16.46% 

# 1618.7 390.9

propane 33.425% 33.425% 33.425% 

# 44.10 14.739 4 33.41% 

# 2314.9 773.8

isobutane 4.619% 4.619% 4.619% 

# 58.12 2.6847 6.09% 

# 3000. 4 138.6

n-butane 15.573% 15.573% 15.573% 

# 58.12 9.0515 20.52% 

# 3010.8 468.9

isopentane 2.605% 2.605% 2.605% 

# 72.15 1.8795 4.26% 

# 3699.0 96.4

n-pentane 3.643% 3.643% 3.643% 

# 72.15 2.628 4 5.96% 

# 3706.9 135.0

n-hexane 0.736% 0.736% 0.736% 

# 86.18 0.6343 1.44% 

# 4403.8 32.4

hexanes, other 1.222% 1.222% 1.222% 

# 84.18 1.0287 2.33% 

# 4403.8 53.8

heptanes 0.987% 0.987% 0.987% 

# 100.21 0.9891 2.24% 

# 5100.0 50.3

octanes 0.035% 0.035% 0.035% 

# 114.23 0.0400 0.09% 

# 5796.1 2.0

nonanes 0.043% 0.043% 0.043% 

# 128.26 0.0552 0.13% 

# 6493.2 2.8

decanes plus 0.002% 0.002% 0.002% 

# 142.29 0.0028 0.01% 

# 7189.6 0.1

benzene 0.047% 0.047% 0.047% 

# 78.11 0.0367 0.08% 

# 3590.9 1.7

toluene 0.019% 0.019% 0.019% 

# 92.14 0.0175 0.04% 

# 4273.6 0.8

ethylbenzene 0.004% 0.004% 0.004% 

# 106.17 0.0042 0.01% 

# 4970.5 0.2

xylenes 0.006% 0.006% 0.006% 

# 106.17 0.006 4 0.01% 

# 4957 0.3

2,2,4-trimethylpentane 0.305% 0.305% 0.305% 

# 114.23 0.348 4 0.79% 

# 5738 17.5

(should total 100%) 

# 100.00% 100.00% 100.00% 44.11 

# 100.00% 2231.4

gas gravity 1.5229

gas rate, mscfd weight % VOC (C3+) 77.41% weight % HAPS 2.37%

mole % VOC 63.27% TANK VENT EMISSION CALCULATION

Marathon Oil Company

# Attachment 3

– Revised Maximum Production Rate with Gas Sales Calculation SheetGREEN= Requires inputRED= No input required. This is a calculated value.Facility InformationMaggie Old Dog USA 24-19HName of the facility, with well numbers (if known).TBDFirst date of production or the date of modification of the facility.9/30/2011Date registration packet is submitted to the NDDoH.Production Data DescriptionAnnual Avg BOPD2200This is the projected facility average BOPD on an annualized basisAnticipated GOR, scf/bbl1000Expected produced oil GORAnnual Avg Treater Gas (Mscfd)2200This is the calculated annual average mscfd of gas for the facility.Oil/Condensate Tank Data DescriptionFlash Gas Method: Default Bakken EFUse the drop down menu to choose the appropriate flash gas method.Bakken EF scf/bbl97.91The scf/bbl from direct measurement or representative sample. If specific data is not available, use the Bakken default of 97.91.Estimated Tank Vapors (scfd)215402This is the estimated scfd of tank vapors based on the following: adjusted BOPD multiplied by the scf/bbl entered under the Production Data sectionLower Heating Value2231Lower heating value (Btu/scf) of tank vapors. If site specific data is not available, use the Bakken default value of 2000.Molecular Weight44.11Molecular weight of the tank vapors in pounds per pound-mole (lb/lb-mole). If site specific data is not available, use the Bakken default value of 45.19.VOC%77.41%VOC weight fraction of the tank vapor gas (C3+). If site specific data is not available, use the Bakken default value of 79.8%.HAP%2.37%HAP weight fraction of the tank vapor gas. If site specific data is not available, use the Bakken default value of 2.26%.H2S weight %0.000%H2S weight percent of the tank vapor gas.H2S mole %0.000%H2S mole percent of the tank vapor gas.Enclosed Smokeless CombustorUse the drop down menu to choose the appropriate emission control type.Control Destruction Efficiency98%Control efficiency of any applicable controls. This is a fixed number based on control type.Treater Gas Data DescriptionBtu/scf1,612Btu/scf of wellstream gas.Molecular Weight28.46Average molecular weight of the wellstream gas in lb/lb-mole.Specific Gravity1If necessary to convert specific gravity to molecular weight, enter the specific gravity of the wellstream gas.Calculated Molecular Weight28.96This is the calculated molecular weight based on the specific gravity entered above.VOC%41.42%VOC weight fraction of the wellstream gas (Note: Weight%, not Mole%).HAP%3.50%HAP weight fraction of the wellstream gas. (Note: Weight%, not Mole%).H2S weight %0.000%H2S weight percent of the wellstream gasH2S mole %0.000%H2S mole percent of the wellstream gasConnected to sales lineUse the drop down menu to choose the appropriate emission control type.Control Destruction Efficiency (DE 1)100%Control efficiency of any applicable controls (combustor, pit flare, utility flare, etc).Hours of Operation8760Hours of Operation at Destruction Efficiency 1Input Data8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Input 1 of 369/30/2011Input DataTreater Burner(s) DescriptionTotal Btu/hr700,000Total burner rating for the heater treater burner(s) in btu/hr. If there are multiple burners, add the total heat input together.Hours of Operation8,760The burner(s) is/are assumed to operate 8,760 hours per year.Truck Loading DescriptionOil is hauled by truckUse the drop down menu to choose the appropriate oil sales method. If oil is sold through a LACT, no input values are requiredfor the Truck Loading DataSubmerged loading: dedicated normal service0.6Use the drop down list to choose the appropriate mode of operation. The saturation factor will automatically be selected basedon mode of operation.Molecular Weight44.11Molecular weight of tank vapors in lb/lb-mole. If no site specific data is available, please refer to Table 2 on the Truck Loading tab.Vapor Pressure1.90True vapor pressure of liquid loaded, pounds per square inch absolute (psia) If no site specific data is available, please refer to Table 2 on the Truck Loading tab.Temperature41.33Temperature of bulk liquid loaded in Fahrenheit. If no site specific data is available, use an estimated average annual temperature.Load Rate (bbl/hr)200Load rate of liquid loaded in barrels per hour.Load Time (hrs)1.00The time it takes to loadout one load (hrs).Pneumatic Pumps DescriptionNumber of Pneumatic Pumps2Number of pneumatic pumps at facility.Hours of Operation4380Hours the pump is in operation annually. For winter months only, please enter 4380 hours.scf/min0.50Pneumatic source consumption rate as per manufacturer data (scf/min).Vented to atmosphereUse the drop down menu to choose the appropriate emission control type.Control Efficiency0%Control efficiency of any applicable controls (combustor, routing exhaust to fuel supply, VRU, etc).Pneumatic Controllers DescriptionNumber of Pneumatic Controllers4Number of pneumatic controllers at facility.Bleed rate (scf/hr)17.40Average bleed rate of device (scf/hr).Glycol Dehydrator DescriptionVOC (TPY)0.00VOC emissions calculated in GRI-GLYCalc software (if no glycol dehydrator enter 0).HAP (TPY)0.00HAP emissions calculated in GRI-GLYCalc software (if no glycol dehydrator enter 0).8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Input 2 of 369/30/2011Number of Engines2RICE Engine #1Hours of Operation120Maximum HP Rating8NOx g/hp-hr4.99CO g/hp-hr3.16VOC g/hp-hr6.8NOx Control Efficiency0%CO Control Efficiency0%VOC Control Efficiency0%RICE Engine #2Hours of Operation120Maximum HP Rating8NOx g/hp-hr4.99CO g/hp-hr3.16VOC g/hp-hr6.8NOx Control Efficiency0%CO Control Efficiency0%VOC Control Efficiency0%RICE Engine #3Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.RICE Input DataEnter the number of engines that will be installed at the production facility.DescriptionRecycle pump engine operates less than 10 hours per month.Manufacturer's maximum hp rating.DescriptionRecycle pump engine operates less than 10 hours per month.Manufacturer's maximum hp rating.8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Rice Input 3 of 369/30/2011RICE Input DataRICE Engine #4Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #5Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #6Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #7Hours of Operation0NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Rice Input 4 of 369/30/2011RICE Input DataMaximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #8Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #9Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #10Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.Manufacturer's maximum hp rating.8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Rice Input 5 of 369/30/2011RICE Input DataNOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #11Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%RICE Engine #12Hours of Operation0Maximum HP Rating100NOx g/hp-hr10CO g/hp-hr5VOC g/hp-hr4NOx Control Efficiency90%CO Control Efficiency75%VOC Control Efficiency70%NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).Manufacturer's emission factor, actual test results or AP-42 factor in grams per horsepower hour (g/hp-hr) for nitrogen oxides(NOx).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for carbon monoxide (CO).Manufacturer's emission factor, actual test results or AP-42 factor in g/hp-hr for total organic compounds (TOC or THC).NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.NOx control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.CO control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.VOC control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.DescriptionEngine is assumed to operate 8,760 hours per year.Manufacturer's maximum hp rating.8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Rice Input 6 of 369/30/2011GREEN= Requires inputRED= No input required. This is a calculated value.Facility InformationMaggie Old Dog USA 24-19HName of the facility and the well number.TBDFirst date of production or the date of modification of the facility.9/30/2011Date registration packet is submitted to the NDDoH.Natural Gas Pneumatic Device Venting DescriptionCount - Total Number of Continuous High Bleed NaturalGas Pneumatic Devices2Count - Total Number of Continuous Low Bleed NaturalGas Pneumatic Devices0Count - Total Number of Intermittent Bleed Natural GasPneumatic Devices0Concentration in Produced Natural Gas - CH447%Concentration of CH4in produced natural gas. For facilities in 98.230(a)(3)-(a)(8), GHGi = 1Concentration in Produced Natural Gas - CO21%Concentration of CO2, in produced natural gas. For facilities in 98.230(a)(3)-(a)(8), GHGi = 1Associated Gas Venting and Flaring DescriptionGas to Oil Ratio (GOR)1000Gas to Oil ratio in cubic feet of gas per barrel of oil. Oil refers to hydrocarbon liquids produced of all API gravities.Volume of Oil Produced (barrels/year)803000Volume of oil produced in barrels in the calendar year during which associated gas was vented or flaredVolumetric Emissions - Gas Venting & Flaring DescriptionTemperature at standard conditions (°F)60Temperature at standard conditions (°F) - TsTemperature at actual emission conditions (°F)60Temperature at actual emission conditions (°F) - TaAbsolute pressure at standard conditions (psia)14.7Absolute pressure at standard conditions (psia) - PsAbsolute pressure at actual conditions (psia)13.6Absolute pressure at actual conditions (psia) - PaMole Fraction in Natural Gas - CH40.47Mole Fraction in Natural Gas - CO20.01115Gas Venting and Flare Stack Emissions DescriptionField Gas or Process Vent GasUse the drop down menu to choose the appropriate type of fuel vented.High Heat Value (HHV)1.235E-03Default High Heat Value based on 40 CFR 98 Table C-1 or 40 CFR 98.233(z)(6)(ii)Percent of Gas Flared100%Percent of gas sent to flare in cubic feet, during the yearFraction of Gas Combusted by Burning Flare100%Fraction of gas combusted by a burning flare (default is 0.98). For gas sent to an unlit flare, n is zeroMole Fraction of Methane0.47Mole fraction of gas hydrocarbon constituentsMole Fraction of Ethane0.26Mole fraction of gas hydrocarbon constituentsMole Fraction of Propane0.15Mole fraction of gas hydrocarbon constituentsMole Fraction of Butane0.0534Mole fraction of gas hydrocarbon constituentsMole Fraction of Pentanes-Plus0.03Mole fraction of gas hydrocarbon constituentsGHG Calculations Input Data1st Calendar Year - Count the total of each type, or count any percentage number of each type plus an engineering estimate based on best available data of the number not counted2nd Calendar Year - Count the total of each type, or count any percentage number of each type plus an engineering estimate based on best available data of the number not counted3rd Calendar Year - Complete the count of all pneumatic devices, including any changes to equipment counted in prior yearsFollowing Years - Update the total count of pneumatic devices and adjust accordingly to reflect any modifications due to changes in equipmentMole fraction of GHGi in the natural gas. 98.233(u)(2) - Annual average mole fraction for each facility as specified in 98.233(u)(2)(i)GHG mole fraction in produced natural gas for onshore petroleum and natural gas production facilities. If you have a continuous gas composition analyzer for produced natural gas, you must usethese values for determining the mole fraction. If you do not have a continuous gas composition analyzer, then you must use your most recent gas composition based on available sample analysisof the field.8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG Calculations Input 7 of 369/30/2011VOC NOx COSO2PMPM10PM2.5Oil/Condensate Tanks 70.84 5.96 32.46 -- -- -- --Treater Flare 0.00 0.00 0.00 0.00 -- -- --Treater Burner 0.02 0.30 0.25 0.002 0.02 0.02 0.02RICE Engine 0.01 0.01 0.01 0.00 0.00 0.00 0.00Truck Loading 16.31 -- -- -- -- -- --Pneumatic Pump 4.09 -- -- -- -- -- --Pneumatic Controllers 4.74 -- -- -- -- -- --Glycol Dehydrator 0.00 -- -- -- -- -- --Totals (TPY) 96.01 6.28 32.71 0.00 0.02 0.02 0.02PSD Threshold* 250 250 250 250 250 250 250Is Threshold Exceeded? No No No No No No NoPSD Modification Threshold* 40 40 100 40 25 15 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 100 100 100 100 100 100Is Threshold Exceeded? No No No No No No NoMinor NSR Rule Threshold*** 5 10 10 10 10 5 3Is Threshold Exceeded?YesNoYesNo No No NoPbNH3FluoridesH2SO4H2STRS RSCOil/Condensate Tanks -- -- -- -- -- -- --Treater Flare -- -- -- -- 0.00 -- --Treater Burner -- -- -- -- -- -- --RICE Engine -- -- -- -- -- -- --Truck Loading -- -- -- -- -- -- --Pneumatic Pump -- -- -- -- -- -- --Pneumatic Controllers -- -- -- -- -- -- --Glycol Dehydrator -- -- -- -- -- -- --Totals (TPY) 0.00 0.00 0.00 0.00 0.00 0.00 0.00PSD Threshold* 250 - 250 250 250 250 250Is Threshold Exceeded? No No No No No No NoPSD Modification Threshold* 0.6 - 3 7 10 10 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 - 100 100 100 100 100Is Threshold Exceeded? No No No No No No NoMinor NSR Rule Threshold*** 0.1 - 12222Is Threshold Exceeded? No No No No No No NoNotes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements**Title V Thresholds taken from the Major Source definition contained in 40 CFR 70.2***Minor NSR Rule Thresholds are found in Table 1 to 40 CFR 49.153, Minor NSR Thresholds (Attainment Areas)*PSD Threshold taken from 40 CFR 52.21(b)(1)(i)(b), oil and gas well facilities are not 1 of the 28 designated source categories listed in 40 CFR 52.21(b)(1)(i)(a) thus theapplicability threshold is 250 tpy. PSD Modification Thresholds taken from 40 CFR 52.21(b)(23)(i).Controlled Criteria Air Pollutants Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryEmission SourceREGULATED CRITERIA AIR POLLUTANTS PTE (TPY) - ControlledREGULATED AIR POLLUTANTS (TPY) - ControlledEmission SourceMarathon Oil CompanyMaggie Old Dog USA 24-19H8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Emission Summary - Controlled9/30/2011VOC NOx COSO2PMPM10PM2.5Oil/Condensate Tanks 3541.80 5.96 32.46 -- -- -- --Treater Flare 12486.62 44.02 239.54 0.00 -- -- --Treater Burner 0.02 0.30 0.25 0.002 0.02 0.02 0.02RICE Engine 0.01 0.01 0.01 0.00 0.00 0.00 0.00Truck Loading 16.31 -- -- -- -- -- --Pneumatic Pump 4.09 -- -- -- -- -- --Pneumatic Controllers 4.74 -- -- -- -- -- --Glycol Dehydrator 0.00 -- -- -- -- -- --Totals (TPY) 16053.59 50.30 272.26 0.002 0.02 0.02 0.02PSD Threshold* 250 250 250 250 250 250 250Is Threshold Exceeded?YesNoYesNo No No NoPSD Modification Threshold* 40 40 100 40 25 15 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 100 100 100 100 100 100Is Threshold Exceeded?YesNoYesNo No No NoMinor NSR Rule Threshold*** 5 10 10 10 10 5 3Is Threshold Exceeded?Yes Yes YesNo No No NoPbNH3FluoridesH2SO4H2STRS RSCOil/Condensate Tanks -- -- -- -- -- -- --Treater Flare -- -- -- -- 0.00 -- --Treater Burner -- -- -- -- -- -- --RICE Engine -- -- -- -- -- -- --Truck Loading -- -- -- -- -- -- --Pneumatic Pump -- -- -- -- -- -- --Pneumatic Controllers -- -- -- -- -- -- --Glycol Dehydrator -- -- -- -- -- -- --Totals (TPY) 0.00 0.00 0.00 0.00 0.00 0.00 0.00PSD Threshold* 250 - 250 250 250 250 250Is Threshold Exceeded? No No No No No No NoPSD Modification Threshold* 0.6 - 3 7 10 10 10Is Threshold Exceeded? N/A N/A N/A N/A N/A N/A N/ATitle V Threshold** 100 - 100 100 100 100 100Is Threshold Exceeded? No No No No No No NoMinor NSR Rule Threshold*** 0.1 - 12222Is Threshold Exceeded? No No No No No No NoNotes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements**Title V Thresholds taken from the Major Source definition contained in 40 CFR 70.2***Minor NSR Rule Thresholds are found in Table 1 to 40 CFR 49.153, Minor NSR Thresholds (Attainment Areas)Uncontrolled Criteria Air Pollutants Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HREGULATED AIR POLLUTANTS (TPY) - UncontrolledEmission Source*PSD Threshold taken from 40 CFR 52.21(b)(1)(i)(b), oil and gas well facilities are not 1 of the 28 designated source categories listed in 40 CFR 52.21(b)(1)(i)(a) thus theapplicability threshold is 250 tpy. PSD Modification Thresholds taken from 40 CFR 52.21(b)(23)(i).REGULATED CRITERIA AIR POLLUTANTS PTE (TPY) - UncontrolledEmission Source8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Emission Summary - Uncontrolled9/30/2011CO2e CO2CH4N2OOil/Condensate Tanks & FugitiveEquipment Leaks****Negligible Negligible Negligible --Gas Venting (Flared)8.96E+04 8.96E+04 2.18E+00 --Gas Venting (Unflared) 0.00E+00 0.00E+00 0.00E+00 --Treater Burner325.44 325.12 0.13 0.19RICE Engine1.04 1.04 -- --Truck Loading-- -- -- --Pneumatic Pump45.27 0.14 2.15 --Pneumatic Controllers163.72 0.50 7.77 --Glycol Dehydrator-- -- -- --Totals (metric tons/year) 90,134 89,880 12 0.19GHG Reporting Threshold* 25,000 -- -- --Note: Subpart W requires reporting these emissions as part of the larger basin reporting.CO2e CO2CH4N2OOil/Condensate Tanks & FugitiveEquipment Leaks****Negligible Negligible Negligible --Gas Venting (Flared) 98765.70 9.87E+04 2.40E+00 --Gas Venting (Unflared) 0.00E+00 0.00E+00 0.00E+00Treater Burner 358.73 358.38 0.14 0.21RICE Engine 1.04 1.04 -- --Truck Loading -- -- -- --Pneumatic Pump 49.90 0.15 2.37 --Pneumatic Controllers 180.47 0.56 8.57 --Glycol Dehydrator -- -- -- --Totals (tpy) 99,355.85 99,075.36 13.48 0.21Title V Threshold** 100,000 -- -- --Is Threshold Exceeded? No -- -- --PSD Threshold*** 100,000 -- -- --Is Threshold Exceeded? No -- -- -- Due to the nature of these types of emissions sources (i.e., oil/condensate tanks and fugitive equipment leaks) potentialemissions of regulated GHG emissions have been assumed to be negligible.Greenhouse Gas Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HGREENHOUSE GAS EMISSIONS PTE (metric tons/year)Emission Source** *PSD Threshold for GHG taken from PSD and Title V Permitting Guidance for Greenhouse Gases prepared by the US EPAOffice of Air Quality Planning and Standards in March 2011. PSD applicability threshold is 75,000 tpy CO2e formodifications at existing PSD sources, 100,000 tpy CO2e for new sources and 100/250 tpy mass basis.**Title V Threshold for GHG taken from PSD and Title V Permitting Guidance for Greenhouse Gases prepared by the USEPA Office of Air Quality Planning and Standards in March 2011.Notes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPArequirements.*GHG Reporting Threshold taken from 40 CFR 98.2(3)(iii).GREENHOUSE GAS EMISSIONS PTE (tpy)Emission Source8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG Emission Summary9/30/2011Total HAPs Benzene Toluene Hexane AcetaldehydeOil/Condensate Tanks 2.17 -- -- -- --Treater Flare 0.00 -- -- -- --Treater Burner 5.67E-03 6.31E-06 1.02E-05 5.41E-03 --RICE Engine -- -- -- -- --Truck Loading -- -- -- -- --Pneumatic Pump 0.35 -- -- -- --Pneumatic Controllers 0.40 -- -- -- --Glycol Dehydrator -- -- -- -- --Totals (TPY) 2.92 (no individual HAP exceeds 10 tpy)Title V Threshold* 25 10 10 10 10Is Threshold Exceeded? NoYesNo No NoNotes: Spreadsheets based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.TreaterflareHAPs conservatively calculatedassuming allC6+ components areHAPs, as an extendedanalysis was not available.HAP Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil Company*HAP thresholds of 10 tpy of an individual regulated HAP and 25 tpy aggregate are taken from the Major Source definition contained in 40CFR 70.2. The thresholds of 10/25 tpy also represent what constitutes a major stationary source.REGULATED HAZARDOUS AIR POLLUTANTS PTE (TPY)Emission SourceMaggie Old Dog USA 24-19H8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, HAP Emission Summary 9/30/2011Oil/Condensate Tanks Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HFlare Gas Volume(scf/day)Lower HeatingValue (Btu/scf)MolecularWeight(lb/lb-mole)VOC wt Fraction(%)HAP wtFraction (%)DestructionEfficiency (%)NOx EmissionFactor(lb/MMBtu)CO EmissionFactor(lb/MMBtu)215402.00 2231.38 44.11 77.41% 2.37% 98% 0.068 0.37PollutantFlare Gas Volume(scf/hr)scf/lb-moleMolecularWeight(lb/lb-mole)wt Fraction(%)Heating Value(Btu/scf)DestructionEfficiency (%)PotentialUncontrolledEmissions(lbs/hr)PotentialUncontrolledEmissions(tons/year)PotentialControlledEmissions(lbs/hr)PotentialControlledEmissions(tons/year)VOC 8975.08 0.0026 44.11 77.41% -- 98% 808.63 3541.80 16.17 70.84HAP8,975.08 0.0026 44.11 2.37% -- 98% 24.81 108.65 0.50 2.17NOx8,975.08-- -- -- 2231.38 -- 1.36 5.965 1.36 5.965CO8,975.08-- -- -- 2231.38 -- 7.41 32.46 7.41 32.46Notes:NOx& CO emission factors are from AP-42 Table 13.5-1 - Emission Factors for Flare Operations.Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirementsEmission estimates reflect combustion related air pollutants. If flare equipped with a pilot burner, heat input of burner should be evaluated.Example CalculationsVOC and HAPS EmissionsPotential Controlled Emissions (lbs/hr) = (Flare Gas Volume (scf/hr) * scf/lb-mole * Molecular Weight (lb/lb-mole) * wt Fraction (%)) * 1 - Destruction Efficiency (%)Potential Controlled Emissions (tons/yr) = Potential Controlled Emissions (lbs/hr) * 8760 hrs/yr * 1/2000NOx and CO EmissionsPotential Controlled Emissions (lbs/hr) = Flare Gas Volume (scf/hr) * Heating Value (Btu/scf) * 1/1,000,000 * Emission Factor (lbs/MMBtu)Potential Controlled Emissions (tons/yr) = Potential Emissions (lbs/hr) * 8760 hrs/yr * 1/20008Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, OilCondensate Tanks9/30/2011Treater Flare Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HFlare GasVolume (scf/day)Lower HeatingValue (Btu/scf)MolecularWeight(lb/lb-mole)VOC wt Fraction(%)HAP wtFraction (%)NOx EmissionFactor(lb/MMBtu)*CO EmissionFactor(lb/MMBtu)*DestructionEfficiency 1(%)**Hours ofOperation at DE 1(hours)DestructionEfficiency 2 (%)**Hours ofOperation at DE 2(hours)2,200,000.00 1612.49 28.46 41.42% 3.50% 0.068 0.37 100% 8760 100% 0PollutantFlare Gas Volume(scf/hr)scf/lb-moleMolecularWeight(lb/lb-mole)wt Fraction(%)Heating Value(Btu/scf)PotentialUncontrolledEmissions(lbs/hr)PotentialUncontrolledEmissions(tons/year)PotentialControlledEmissions 1(lbs)PotentialControlledEmissions 1(tons)PotentialControlledEmissions 2(lbs)PotentialControlledEmissions 2(tons)Potential TotalControlledEmissions(lbs/hr)Potential TotalControlledEmissions(tons/year)VOC 91,666.67 0.0026 28.46 41.42% -- 2850.83 12486.62 0.00 0.00 0.00 0.00 0.00 0.00HAP91,666.67 0.0026 28.46 3.50% -- 240.74 1054.43 0.00 0.00 0.00 0.00 0.00 0.00H2S91,666.670.0026 28.46 0.00% -- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00SO291,666.670.0026 64.00 0.00% -- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00NOx91,666.67-- -- -- 1612.49 10.05 44.02 -- -- -- -- 0.00 0.00CO91,666.67 -- -- -- 1612.49 54.69 239.54 -- -- -- -- 0.00 0.00Notes:*NOx& CO emission factors are from AP-42 Table 13.5-1 - Emission Factors for Flare Operations.**100% destruction efficiency means that the treater gas is routed and connected to the sales line (gas gathering pipeline).Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Example CalculationsVOC and HAPS EmissionsPotential Controlled Emissions (lbs/hr) = (Flare Gas Volume (scf/hr) * scf/lb-mole * Molecular Weight (lb/lb-mole) * wt Fraction (%)) * 1 - Destruction Efficiency (%)Potential Controlled Emissions (tons/yr) = Potential Controlled Emissions (lbs/hr) * Hours of Operation * 1/2000NOx and CO EmissionsPotential Controlled Emissions (lbs/hr) = Flare Gas Volume (scf/hr) * Heating Value (Btu/scf) * 1/1,000,000 * Emission Factor (lbs/MMBtu)Potential Emissions (tons/yr) = Potential Emissions (lbs/hr) * 8760 hrs/yr * 1/20008Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Treater Flare9/30/2011Treater Burner Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HBurner Rating(Btu/hr)Burner Rating(MMBtu/hr)Average NaturalGas HigherHeating Value(Btu/scf)NOx EmissionFactor(lb/106scf)CO EmissionFactor(lb/106scf)PM (Total)Emission Factor(lb/106scf)PM(Condensable)Emission Factor(lb/106scf)PM (Filterable)Emission Factor(lb/106scf)SO2EmissionFactor(lb/106scf)VOC EmissionFactor(lb/106scf)HAP EmissionFactor(lb/106scf)700,000.00 0.70 1,020 100 84 7.6 5.7 1.9 0.6 5.5 1.9PollutantEmission Factor(lb/MMBtu)Burner Rating(MMBtu/hr)PotentialEmissions(lbs/hr)PotentialEmissions(tons/year)NOx 0.10 0.70 0.07 0.30CO0.08 0.70 0.06 0.25PM (Total)0.007 0.70 0.005 0.02PM (Condensable)0.006 0.70 0.0040.02PM (Filterable)0.002 0.70 0.001 0.006SO20.001 0.70 0.00040.002VOC0.005 0.70 0.0040.02HAPs0.002 0.70 0.001 0.006Notes:NOx, CO, PM, HAP, SO2 & VOC Emission Factors are from AP-42, Section 1.4 - Natural Gas Combustion, Tables 1.4-1, 1.4-2, and 1.4-3.Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Example CalculationsPotential Emissions (lbs/hr) = Emission Factor (lbs/MMBtu) * Burner Rating (MMBtu/hr)Potential Emissions (tons/yr) = Potential Emissions (lbs/hr) * 8760 hrs/yr * 1/20008Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Treater Burner9/30/2011Treater Burner - Regulated HAPs Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HFormaldehyde Yes 7.35E-05 AP-42 Nat. Gas Comb. (7/98), Table 1.4-35.15E-05 2.25E-042-Methylnaphthalene Yes 2.35E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.65E-08 7.21E-083-Methylchloranthrene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-097,12-Dimethylbenz(a)anthracene Yes 1.57E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.10E-08 4.81E-08Acenaphthene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Acenaphthylene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Anthracene Yes 2.35E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.65E-09 7.21E-09Arsenic Yes 1.96E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.37E-07 6.01E-07Benz(a)anthracene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Benz(a)pyrene Yes 1.18E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-10 3.61E-09Benzene Yes 2.06E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.44E-06 6.31E-06Benzo(b)fluoranthene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Benzo(g,h,i)perylene Yes 1.18E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-10 3.61E-09Benzo(k)fluoranthene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Beryllium Yes 1.18E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-48.24E-09 3.61E-08Cadmium Yes 1.08E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-47.55E-07 3.31E-06Chromium Yes 1.37E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-49.61E-07 4.21E-06Chrysene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Cobalt Yes 8.24E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-45.76E-08 2.52E-07Dibenzo(a,h)anthracene Yes 1.18E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-10 3.61E-09Dichlorobenzene Yes 1.18E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-38.24E-07 3.61E-06Fluoranthene Yes 2.94E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-32.06E-09 9.02E-09Fluorene Yes 2.75E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.92E-09 8.42E-09Hexane Yes 1.76E-03 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-03 5.41E-03Indeno(1,2,3-cd)pyrene Yes 1.76E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.24E-09 5.41E-09Manganese Yes 3.73E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-42.61E-07 1.14E-06MercuryYes 2.55E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.78E-07 7.82E-07Naphthalene Yes 5.98E-07 AP-42 Nat. Gas Comb. (7/98), Table 1.4-34.19E-07 1.83E-06Nickel Yes 2.06E-06 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.44E-06 6.31E-06Phenanathrene Yes 1.67E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-31.17E-08 5.11E-08Pyrene Yes 4.90E-09 AP-42 Nat. Gas Comb. (7/98), Table 1.4-33.43E-09 1.50E-08Selenium Yes 2.35E-08 AP-42 Nat. Gas Comb. (7/98), Table 1.4-41.65E-08 7.21E-08Toluene Yes 3.33E-06AP-42 Nat. Gas Comb. (7/98), Table 1.4-32.33E-06 1.02E-05Total (TPY)= 0.006EquipmentHeat Input(MMBtu/hr)Hours of Operation(hrs/yr)Treater Burner0.7 8760TOTAL 0.7Notes:*Regulated under Section 112(b) for Clean Air Act.Example CalculationEstimated Uncontrolled Emissions (lbs/hr) = Emission Factor (lbs/MMBtu) x Heat Input Rate (MMBtu/hr)Estimated Uncontrolled Emissions (tons/yr) = Estimated Uncontrolled Emissions (lbs/hr) x Hours of Operation / 2000Estimated Uncontrolled Emissions(tons/yr)**Emission factors taken from AP-42, Chapter 1 - External Combustion Sources, Table 1.4-3 - Emission Factors for Speciated Organic Compounds from Natural Gas Combustion andTable 1.4-4 - Emission Factors for Metals from Natural Gas Combustion.PollutantHAP*Yes/NoEmission Factor(lb/MMBtu)**Emission Factor SourceEstimated Uncontrolled Emissions(lb/hr)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Treater Burner - HAPs9/30/2011Truck Loading Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HCargo Carrier Mode of Operation S FactorSubmerged loading of a clean cargotank0.50Submerged loading: dedicatednormal service0.60Submerged loading: dedicated vaporbalance service1.00Table 2 - Vapor Pressure and Molecular Weight Values40 50 60 70 80 90 100Crude Oil RVP 5 50 4.5 7.1 1.8 2.3 2.8 3.4 4.0 4.8 5.7Values based on AP-42, Chapter 7 - Liquid Storage Tanks, Table 7.1-2 - Properties (Mv, PVA, WL) of Selected Petroleum Liquids.Constant Saturation Factor (S)Vapor Pressure (P)(psi)MolecularWeight (M)(lb/lb-mole)Temperature (T)(°R)Loading Loss(lb/1,000 gal)12.46 0.60 1.90 44.11 501 1.25Loading Loss(lb/1,000 gal)Truck Load Rate (bbl/hr)Truck Load Time(hrs)gal/bbl Annual bbl/yrPotentialUncontrolled VOCEmissions(lbs/hr)PotentialUncontrolled VOCEmissions(tons/yr)PotentialUncontrolled C3+VOC Emissions*(tons/yr)1.25 200.00 1.00 42.00 803000.00 10.50 21.08 16.31Notes:*VOC weight fraction of the tank vapor gas (C3+). If site specific data is not available, use the Bakken default value of 79.8%.UncontrolledPotential VOCEmissions(tons/yr)Control (%) 1 - Control (%)ControlledPotential VOCEmissions(tons/yr)16.31 0.00 1.00 16.31Notes:Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirementsExample CalculationsLoading Loss (lb/1,000 gal) = Constant * Saturation Factor * Vapor Pressure * (Molecular Weight / Temperature)Potential Emissions (lbs/hr) = Loading Loss / 1000 * (Truck Load Rate / Truck Load Time) * gal/bblUncontrolled Potential Emissions (tons/yr) = (Loading Loss / 1000) * Annual bbl/yr * gal/bbl / 2000Controlled Potential Emissions (tons/yr) = Uncontrolled Emissions * 1 - Control EfficiencyAP-42 EquationLL = 12.46 x (S x P x M)/TLL = Loading loss, pound per 1,000 gallons of liquid loaded (lb/1000 gal)S = Saturation factor (AP-42 Table 5.2-1)P = True vapor pressure of liquid loaded (psia) (AP-42 Table 7.1-2)M = Molecular weight of tank vapors (lb/lb-mol) (AP-42 Table 7.1-2)T = Temperature of bulk liquid loaded (°R) (°R = °F + 460)Table 1 - Saturation Factor VariableTank Trucks and RailTank CarsFactors based on AP-42, Section 5.2 - Transportation and Marketing of PetroleumLiquids, Table 5.2-1 - Saturation (S) Factors for Calculating Petroleum LiquidLoading Losses.True Vapor Pressure(psi) at various temperatures in °FPetroleum LiquidVapor MW at 60°F(lb/lb-mole)Condensed VaporDensityat 60°F (lb/gal)Liquid Density at60°F (lb/gal)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Truck Loading9/30/2011Reciprocating Internal Combustion Gasoline Engines (RICE) Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEngine # Maximum HPHours ofOperation***NOxDRE (%)**NOx Emission Factor(g/HP-HR)*CO DRE (%)**CO Emission Factor(g/HP-HR)*VOC DRE (%)**VOC Emission Factor(g/HP-HR)*PM10EmissionFactor(g/HP-HR)*SO2EmissionFactor(g/HP-HR)*CO2EmissionFactor(g/HP-HR)*Engine #1 8.00 120.00 0% 4.99 0% 3.16 0% 6.80 0.33 0.27 489.89Engine #2 8.00 120.00 0% 4.99 0% 3.16 0% 6.80 0.33 0.27 489.89Engine #3 100.00 0 90% 10.00 75% 5.00 70% 4.00 0.33 0.27 489.89Engine #4 100.00 0 90% 10.00 75% 5.00 70% 4.00 0.33 0.27 489.89Notes:**Control efficiency of any applicable controls (NSCR catalyst, AFRC, etc) obtained from manufacturer data or actual test results.***Engine is assumed to operate 8,760 hours per year.Uncontrolled EmissionsPollutantEngine #1 PotentialEmissions (lbs/hr)Engine #1 PotentialEmissions (tons/yr)Engine #2 PotentialEmissions (lbs/hr)Engine #2 PotentialEmissions (tons/yr)Engine #3 PotentialEmissions (lbs/hr)Engine #3 PotentialEmissions (tons/yr)Engine #4 PotentialEmissions (lbs/hr)Engine #4 PotentialEmissions (tons/yr)Total PotentialUncontrolledEmissions (lbs/hr)Total PotentialUncontrolledEmissions(tons/yr)NOx 0.09 0.01 0.09 0.01 2.20 0.00 2.20 0.00 4.59 0.01CO0.06 0.00 0.06 0.00 1.10 0.00 1.10 0.00 2.32 0.01VOC0.12 0.01 0.12 0.01 0.88 0.00 0.88 0.00 2.00 0.01PM100.01 0.00 0.01 0.00 0.07 0.00 0.07 0.00 0.16 0.00SO20.005 0.00 0.00 0.00 0.06 0.00 0.06 0.00 0.13 0.00CO28.64 0.52 8.64 0.52 108.00 0.00 108.00 0.00 233.28 1.04Controlled EmissionsPollutantEngine #1 PotentialEmissions (lbs/hr)Engine #1 PotentialEmissions (tons/yr)Engine #2 PotentialEmissions (lbs/hr)Engine #2 PotentialEmissions (tons/yr)Engine #3 PotentialEmissions (lbs/hr)Engine #3 PotentialEmissions (tons/yr)Engine #4 PotentialEmissions (lbs/hr)Engine #4 PotentialEmissions (tons/yr)Total PotentialControlledEmissions (lbs/hr)Total PotentialControlledEmissions(tons/yr)NOx 0.09 0.01 0.09 0.01 0.22 0.00 0.22 0.00 0.62 0.01CO0.06 0.00 0.06 0.00 0.28 0.00 0.28 0.00 0.66 0.01VOC0.12 0.01 0.12 0.01 0.26 0.00 0.26 0.00 0.77 0.01PM100.01 0.00 0.01 0.00 0.07 0.00 0.07 0.00 0.16 0.00SO20.005 0.00 0.00 0.00 0.06 0.00 0.06 0.00 0.13 0.00CO28.640 0.52 8.64 0.52 108.00 0.00 108.00 0.00 233.28 1.04Notes:Calculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Total Combined HP:216.00Total Hours of Operation:240.00Example CalculationsPotential Controlled Emissions (lbs/hr) = HP x Emission Factor (g/HP-hr) / Conversion Factor x 1 - Control EfficiencyPotential Controlled Emissions (tons/yr) = Potential Emissions (lbs/hr) * Hours of Operation / 2000*Emission factors for NOx, CO and VOC are based on Manufacturer's emission factor, actual test results, or AP-42 factor in grams per horsepower hour (g/hp-hr).Emission factors for PM10,SO2,and CO2are taken from AP-42, Table 3.3-1 - Emission Factors for Uncontrolled Gasoline and Diesel Industrial Engines. Factors are converted to g/hp-hr from lb/hphr.8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, RICE Engines9/30/2011Pneumatic Pumps Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HPneumatic SourceConsumptionRate* (scf/min)Supply GasMolecularWeight**(lb/lb-mole)VOC wt Fraction(%)HAP wt Fraction(%)Hours ofOperation***(hrs/yr)ControlEfficiency (%)Number ofPumpsPotentialUncontrolledVOC Emissions(lbs/hr)PotentialUncontrolled VOCEmissions(tons/yr)PotentialControlled VOCEmissions(tons/yr)PotentialUncontrolledHAP Emissions(lbs/hr)PotentialUncontrolled HAPEmissions(tons/yr)Potential ControlledHAP Emissions(tons/yr)0.50 28.46 41.42% 3.50% 4380 1.00 2.0 0.93 4.1 4.1 0.08 0.3 0.3Notes:*PSCR = Pneumatic Source Consumption Rate (scf/min), as per manufacturers literature.**Gas MW = Supply Gas Average Molecular Weight (lb/lb-mole).***Hours the pump is in operation annually. For winter months only, please enter 4380 hours.Example CalculationsCalculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Potential Controlled Emissions (lb/hr) = PSCR (scf/min) x (60 min/1hr) x (1/379 scf/lb-mole) x Supply Gas MW x VOC wt. Fractionx Control EfficiencyPotential Controlled Emissions (tons/yr) = lb/hr VOC x Hours of Operation x 1 ton/2000 x Number of Pumps8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Pneumatic Pump9/30/2011Pneumatic Controllers Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HPneumatic SourceConsumptionRate* (scf/hr)Supply GasMolecularWeight**(lb/lb-mole)VOC wt Fraction(%)HAP wt Fraction(%)Hours ofOperation***(hrs/yr)Number ofControllersPotential VOCEmissions(lbs/hr)Potential VOCEmissions(tons/yr)Potential HAPEmissions(lbs/hr)Potential HAPEmissions(tons/yr)17.40 28.46 41.42% 3.50% 4380 4.0 0.54 4.7 0.05 0.4Notes:*PSCR = Pneumatic Source Consumption Rate (scf/min), as per manufacturers literature.**Gas MW = Supply Gas Average Molecular Weight (lb/lb-mole).***Hours the pump is in operation annually. For winter months only, please enter 4380 hours.Example CalculationsCalculations based on forms provided by North Dakota Department of Health and updated to reflect EPA requirements.Potential Emissions (lb/hr) = PSCR (scf/min) x (60 min/1hr) x (1/379 scf/lb-mole) x Supply Gas MW x VOC wt. FractionPotential Emissions (tons/yr) = lb/hr VOC x Hours of Operation x 1 ton/2000 x Number of Pumps8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Pneumatic Controller9/30/2011

# Tank Flare Combustion - Greenhouse Gases Emission Summary

US EPA - Region 8 Air Program

Federal New Source Review Program in Indian Country

Marathon Oil Compan y

Maggie Old Dog USA 24-19H

CO2 from

Component "I" Gas Burned

(scf) G as M o l

Fraction

of "I" M o l

Factor

of "I" Conversion

Factor @100%

Tonnes

CO 2 

# Flare @ 98%,

tonnes

CH4 

# 78,621,730 0.07242 1 0.0000526 299.5 294

C2H6 78,621,730 0.24148 2 0.0000526 1997.3 1,957

C3H8 78,621,730 0.33425 3 0.0000526 4146.9 4,064

Iso-C4H10 78,621,730 0.04619 4 0.0000526 764.1 749

Nor-C4H10 78,621,730 0.15573 4 0.0000526 2576.1 2,525

Iso-C5H12 78,621,730 0.02605 5 0.0000526 538.6 528

Nor-C5H12 78,621,730 0.03643 5 0.0000526 753.3 738

C6 and + 78,621,730 0.03406 6 0.0000526 845.1 828

CO2 78,621,730 0.00285 1 0.0000526 11.8 12

0.94946 tonnes CO2 from combustion 11,694

uncombusted methane as CO2e 46

total tankflare GHG as CO2e, tonnes 11,740

tpy 12,943 

# Tank Flare Gas GHG EmissionsNatural Gas Combustion (Treater Burner) - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEmission Factor Tablevalue custom default units value custom default units value custom default units value custom default unitsNatural Gas Fossil-gaseous 0.001028 1.028E-03 MMBtu/scf 53.02 53.02 kg/MMBtu 0.001 1.0E-03 kg/MMBtu 0.0001 1.0E-04 kg/MMBtuNotes:a) Default values for natural gas were obtained from the EPA Greenhouse Gas Reporting Rule (10/30/2009) Tables C-1 and C-2.b) Please convert any custom values to the specified default units.Annual GHG Calculation(By GHG Rule Eq. C-2a and C-2b)Fuel Use(MMBtu/hr)Fuel Use(MMBtu/yr)Calculation Tier(a)0.70 6,132 Tier 1CO2CH4N2OTOTAL53.02 0.001 0.0001 --325 0.006 0.0006 --1 21 310 --325 0.13 0.19 325358 0.14 0.21 359Notes:Color Key:Required DataOptional Data (Provide if Available)CH4Emission Factor N2O Emission FactorEstimated GHG Emissions (tons CO2e)b) Emission factors (EF) for natural gas were obtained from Tables C-1 and C-2 of the EPA Greenhouse GasReporting Rule (40 CFR 98).c) Global warming potentials (GWP) were obtained from Table A-1 of the EPA Greenhouse Gas Reporting Rule (40CFR 98).Fuel Fuel ClassificationHigher Heating ValueCO2Emission FactorParameterEF(b)(kg/MMBtu)Estimated GHG Emissions (metric tons)GWP(c)(kg CO2e/kg)Estimated GHG Emissions (metric tons CO2e)a) The default HHV value from Table C-1 of the EPA Greenhouse Gas Reporting Rule is substituted when no actualHHV data from fuel sampling is available. Use of the default HHV value constitutes the Tier 1 calculation methodwhile use of HHV values obtained from fuel sampling constitutes Tier 2.8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Natural Gas9/30/2011Natural Gas Pneumatic Device Venting - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEmission Factor Table*PopulationEmission Factors -All Components,Gas ServiceValve Connector Open-Ended Line Pressure Relief ValveLow Continuous BleedPneumatic DeviceVents**High Continuous BleedPneumatic DeviceVents**Intermittent BleedPneumatic DeviceVents**Pneumatic Pumps**Emission Factor(scf/hour/component)0.123 0.017 0.032 0.196 1.8 48.1 17.4 13.3Notes:*Default values were obtained from the EPA Greenhouse Gas Reporting Rule Table W-1A - Default Whole Gas Emission Factors for Onshore Petroleum and Natural Gas Production (Western U.S.)**Emission Factor is in units of scf/hour/device or scf/hour/pumpAnnual GHG CalculationCount - ContinuousHigh BleedEF - Continuous HighBleed(scf/hour/device)Count - ContinuousLow BleedEF - Continuous LowBleed(scf/hour/device)Count - IntermittentBleedEF - IntermittentBleed(scf/hour/device)Concentration of CH4inProduced Natural Gas(GHGi)Concentration of CO2inProduced Natural Gas(GHGi)Conversion (Convi)from standard cubicfeet CH4tometric tons CO2eConversion (Convi)from standard cubicfeet CO2tometric tons CO2eGlobal WarmingPotential (GWP) - CH4(kg CO2e/kg)2.0 48.1 0.0 1.8 0.0 17.4 47% 1% 0.000410 0.00005357 21Emissions in Metric Tons CO2e (GHG Rule Eq. W-1)ContinuousHigh Bleed -CH4Emissions(metric tons CO2e)ContinuousHigh Bleed -CO2Emissions(metric tons CO2e)ContinuousLow Bleed -CH4Emissions (metrictons CO2e)ContinuousLow Bleed -CO2Emissions (metrictons CO2e)Intermittent Bleed -CH4Emissions(metric tons CO2e)Intermittent Bleed -CO2Emissions (metrictons CO2e)TotalCH4Emissions(metric tons CO2e)TotalCO2Emissions(metric tons CO2e)TotalGHG Emissions(metric tons CO2e)163.22 0.50 0.00 0.00 0.00 0.00 163.22 0.50 163.72Emissions in Metric Tons CH4ContinuousHigh Bleed(metric tons CH4)ContinuousLow Bleed -(metric tons CH4)Intermittent Bleed -(metric tons CH4)TotalCH4Emissions (metrictons CH4)7.77 0.00 0.00 7.77Notes:a) Calculation for Natural Gas Pneumatic Device Venting found in 98.233(a) Equation W-1 -Masss,I = Count * EF * GHGi * Convi * 24 *365Masss,I= Annual total mass GHG emissions in metric tons CO2eCount = Total number of continuous high bleed, continuous low bleed, or intermittent bleed natural gas pneumatic devices of each typeEF = Population emission factorsGHGi= Concentration of GHGi, CH4or CO2in produced natural gas (For facilities in 98.230(a)(3)-(a)(8), GHGi = 1)Convi= Conversion from scf to metric tons CO2e, 0.000410 for CH4or 0.00005357 for CO2b) Global warming potentials (GWP) were obtained from Table A-1 of the EPA Greenhouse Gas Reporting Rule (40 CFR 98).8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Pneumatic Device Venting9/30/2011Natural Gas Pneumatic Pumps - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HEmission Factor Table*PopulationEmission Factors -All Components,Gas ServicePneumatic Pumps**Emission Factor(scf/hour/component)13.3Notes:*Default values were obtained from the EPA Greenhouse Gas Reporting Rule Table W-1A - Default Whole Gas Emission Factors for Onshore Petroleum and Natural**Emission Factor is in units of scf/hour/device or scf/hour/pumpAnnual GHG CalculationCount - PneumaticPumpsEF - PneumaticPumps(scf/hour/device)Concentration of CH4in Produced NaturalGas(GHGi)Concentration of CO2in Produced NaturalGas(GHGi)Conversion (Convi)from standard cubicfeet CH4tometric tons CO2eConversion (Convi)from standard cubicfeet CO2tometric tons CO2eGlobal WarmingPotential (GWP) - CH4(kg CO2e/kg)2.0 13.3 47.2% 1.115% 0.000410 0.00005357 21Emissions in Metric Tons CO2e (GHG Rule Eq. W-1)Pneumatic PumpsCH4Emissions(metric tons CH4)Pneumatic PumpsCH4Emissions(metric tons CO2e)Pneumatic PumpsCO2Emissions (metrictons CO2e)TotalGHG Emissions(metric tons CO2e)2.15 45.13 0.14 45.27Notes:a) Calculation for Natural Gas Pneumatic Device Venting found in 98.233(a) Equation W-2 -Masss,I = Count * EF * GHGi * Convi * 24 *365Masss,I= Annual total mass GHG emissions in metric tons CO2eCount = Total number of natural gas pneumatic pumpsEF = Population emission factorsGHGi= Concentration of GHGi, CH4or CO2in produced natural gas (For facilities in 98.230(a)(3)-(a)(8), GHGi = 1)Convi= Conversion from scf to metric tons CO2e, 0.000410 for CH4or 0.00005357 for CO2b) Global warming potentials (GWP) were obtained from Table A-1 of the EPA Greenhouse Gas Reporting Rule (40 CFR 98).8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Pneumatic Pumps9/30/2011Gas Production (Western U.S.).8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Pneumatic Pumps9/30/2011Associated Gas Venting and Flaring - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HAnnual Volumetric Natural Gas Emissions (cubic feet) (GHG Rule Eq. W-18)Gas to Oil Ratio (GOR)(cubic feet ofgas/barrel of oil)Volume of Oil Produced(V)(barrels/year)Annual VolumetricNatural Gas Emissions(Ea,n) (cubic feet)Percent of AnnualVolumetric NaturalGas Not Flared (%)Annual VolumetricNatural Gas Emissions -Not Flared (cubic feet)1,000.00803,000.00803,000,000.000% 0.00Calculation for Venting Emissions found in 98.233(m) Equation W-18Ea,n= GOR * VNatural Gas Volumetric Emissions - Standard Conditions (GHG Rule Eq. W-33)Natural Gas VolumetricEmissions at ActualConditions (Ea,n) (cubicfeet)Temperature atStandard Conditions (Ts)(°F)Temperature at ActualEmission Conditions(Ta) (°F)Absolute Pressure atStandard Conditions(Ps) (psia)Absolute Pressure atActual Conditions(Pa) (psia)Natural Gas VolumetricEmissions at STP(Es,n) (cubic feet)0.00 60.00 60.00 14.70 13.60 0.00Calculation for Natural Gas Volumetric Emissions - Standard Conditions found in 98.233(t) Equation W-33GHG Volumetric Emissions (cubic feet) (GHG Rule Eq. W-35)Natural Gas VolumetricEmissions at ActualConditions (Es,n) (cubicfeet)Mole Fraction (Mi) - CH4Mole Fraction (Mi) -CO2CH4VolumetricEmissions at STP (Es,i)(cubic feet)CO2Volumetric Emissionsat STP (Es,i)(cubic feet)0.00 0.47 0.01 0.00 0.00Calculation for GHG Volumetric Emissions found in 98.233(u) Equation W-35Es,i= Es,n* MiGHG Mass Emissions (metric tons CO2e) (GHG Rule Eq. W-36)CH4VolumetricEmissions at STP (Es,i)(cubic feet)CO2VolumetricEmissions at STP (Es,i)(cubic feet)Density (Pi) of CO2Density (Pi) of CH4Global WarmingPotential (GWP) of CO2(kg CO2e/kg)Global Warming Potential(GWP) of CH4(kg CO2e/kg)Mass Emissions atStandard Conditions(Massi) - CO2(metric tons CO2e)Mass Emissions atStandard Conditions(Massi) - CH4(metric tons CO2e)Mass Emissions at StandardConditions (Massi) - Total(metric tons CO2e)Mass Emissions atStandard Conditions(Massi) - CH4(metric tons CH4)0.00 0.00 0.0538 0.0196 1 21 0.00E+00 0.00E+00 0.00E+00 0.00E+00Calculate GHG mass emissions in CO2e at standard conditions by converting the GHG volumetric emissions into mass emissionsCalculation for GHG Mass Emissions found in 98.233(v) Equation W-36Masss,i= Es,i* Pi* GWP * 10-3*Density was assumed to be at standard conditions, 68°F and 14.7 psia.Es,i = GHGi (either CH4 or CO2) volumetric emissions at standard conditions in cubic feetEs,n = Natural gas volumetric emissions at standard conditions in cubic feetMi = Mole fraction of GHGi in the natural gas. 98.233(u)(2) - Annual average mole fraction for each facility as specified in 98.233(u)(2)(i) - GHG mole fractionin produced natural gas for onshore petroleum and natural gas production facilities. If you have a continuous gas compositionanalyzer for produced naturalgas, you must use these values for determining the mole fraction. If you do not have a continuous gas composition analyzer, then you must use your mostrecent gas composition based on available sample analysis of the field.Masss,i= GHGi(either CH4or CO2) mass emissions at standard conditions in metric tons CO2eEs,i= GHGi(either CH4 or CO2) volumetric emissions at standard conditions in cubic feetPi= Density of GHGi. Use 0.0538 kg/ft3for CO2and N2O, and 0.0196 kg/ft3for CH4at 68°F and 14.7 psia or 0.0530 kg/ft3for CO2and N2O, and 0.0193 kg/ft3for CH4at 60°F and 14.7 psia.GWP= Global warming potential, 1 for CO2, 21 for CH4, and 310 for N2OEa,n= Annual volumetric natural gas emissions from associated gas venting, in cubic feetGOR= Gas to oil ratio in cubic feet of gas per barrel of oil; oil here refers to hydrocarbon liquids produced of all API gravitiesV= Volume of oil produced in barrels in the calendar year during which associated gas was vented or flaredEs,n= Ea,n* (459.67 + Ts) * Pa(459.67 + Ta) * PsEs,n= Natural gas volumetric emissions at standard temperature and pressure (STP) conditions in cubic feetEa,n= Natural Gas Volumetric Emissions at Actual Conditions in Cubic FeetTs= Temperature at standard conditions (°F)Ta= Temperature at actual emission conditions (°F)Ps= Absolute pressure at standard conditions (psia)Pa= Absolute pressure at actual conditions (psia)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Gas Venting (Unflared)9/30/2011Flare Stack Emissions - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HGHG Volumetric Emissions at Actual Conditions (cubic feet)Annual Un-Combusted CH4Emissions (cubic feet) (GHG Rule Eq. W-19)Volume of Gas Flared(Va)(cubic feet/yr)Fraction of GasCombusted byBurning Flare (n) (%)Mole Fraction of CH4inFlared Gas (XCH4)AnnualUn-Combusted CH4Emissions (Ea,CH4)(cubic feet)803,000,000.00 100% 0.47 0.0000Calculation for Flare Stack Emissions - Annual Un-Combusted CH4 Emissions found in 98.233(n) Equation W-19Ea,CH4(un-combusted) = Va* (1 - n) * XCH4Annual Un-Combusted CO2Emissions (cubic feet) (GHG Rule Eq. W-20)Volume of Gas Flared(Va)(cubic feet/yr)Mole Fraction of CO2in Flared Gas (XCO2)AnnualUn-Combusted CO2Emissions (Ea,CO2)(cubic feet)803,000,000.00 0.01 8,956,662.00Calculation for Flare Stack Emissions - Annual Un-Combusted CO2 Emissions found in 98.233(n) Equation W-20Ea,CO2(un-combusted) = Va* XCO2Annual Combusted CO2Emissions (cubic feet) (GHG Rule Eq. W-21)Volume of Gas Flared(Va)(cubic feet/yr)Fraction of GasCombusted byBurning Flare (n)(%)AnnualCombusted CO2Emissions (Ea,CO2)(cubic feet)803,000,000.00 100% 1,438,233,225.00Calculation for Flare Stack Emissions - Annual Combusted CO2 Emissions found in 98.233(n) Equation W-21Ea,CO2(combusted) =∑jn * Va* Yj* RjEa,CH4(un-combusted)= Contribution of annual un-combusted CH4emissions from flare stack in cubic feet, under actual conditionsVa= Volume of gas sent to flare in cubic feet, during the yearn= Fraction of gas combusted by a burning flare (default is 0.98). For gas sent to an unlit flare, n is zeroXCH4= Mole fraction of CH4in gas to the flareEa,CO2(un-combusted)= Contribution of annual un-combusted CO2emissions from flare stack in cubic feet, under actual conditionsVa= Volume of gas sent to flare in cubic feet, during the yearXCO2= Mole fraction of CO2in gas to the flareEa,CO2(combusted)= Contribution of annual combusted CO2emissions from flare stack in cubic feet, under actual conditionsVa= Volume of gas sent to flare in cubic feet, during the yearn= Fraction of gas combusted by a burning flare (default is 0.98). For gas sent to an unlit flare, n is zeroYj= Mole fraction of gas hydrocarbon constituents j (such as methane, ethane, propane, butane, and pentanes-plus)Rj= Number of carbon atoms in the gas hydrocarbon constituents j: 1 for methane, 2 for ethane, 3 for propane, 4 for butane, and5 for pentane plus8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Flare Stacks9/30/2011Flare Stack Emissions - Greenhouse Gases Emission SummaryUS EPA - Region 8 Air ProgramFederal New Source Review Program in Indian CountryMarathon Oil CompanyMaggie Old Dog USA 24-19HNatural Gas Volumetric Emissions - Standard Conditions (GHG Rule Eq. W-33)Natural Gas VolumetricEmissions at ActualConditions (Ea,n) (cubicfeet)Temperature atStandard Conditions(Ts) (°F)Temperature at ActualEmission Conditions (Ta)(°F)Absolute Pressure atStandard Conditions (Ps)(psia)Absolute Pressure atActual Conditions (Pa)(psia)Natural Gas VolumetricEmissions at STP (Es,n)(cubic feet)803,000,000.00 60.00 60.00 14.70 13.60 742,911,564.63Calculation for Natural Gas Volumetric Emissions - Standard Conditions found in 98.233(t) Equation W-33GHG Mass Emissions (metric tons CO2e) (GHG Rule Eq. W-36)CH4VolumetricEmissions at STP (Es,i)(cubic feet)CO2VolumetricEmissions at STP (Es,i)(cubic feet)Density (Pi) of CO2Density (Pi) of CH4Global Warming Potential(GWP) of CO2(kg CO2e/kg)Global Warming Potential(GWP) of CH4(kg CO2e/kg)Mass Emissions at StandardConditions (Massi) - CO2(metric tons CO2e)Mass Emissions at StandardConditions (Massi) - CH4(metric tons CO2e)Mass Emissions at StandardConditions (Massi) - Total(metric tons CO2e)Mass Emissions atStandard Conditions(Massi) - CH4(metric tons CH4)0.00 1,447,189,887.00 0.0538 0.0196 1 21 7.79E+04 0.00E+00 7.79E+04 0.00E+00Calculate GHG mass emissions in CO2e at standard conditions by converting the GHG volumetric emissions into mass emissionsCalculation for GHG Mass Emissions found in 98.233(v) Equation W-36Masss,i= Es,i* Pi* GWP * 10-3*Potential N2O emissions from fuel combustion in the flare are assumed to be negligible.**Density was assumed to be at standard conditions, 68°F and 14.7 psia.Subpart W Equation W-40 Treater Flare Negligibility CheckHHV, mmBtu/scf (eq. W-40) 1.235E-03EF, kg N2O/mmBtu 1.00E-04convert kg to metric tons1.00E-03combusted gas volume, scf/yr803,000,000N2O, metric tons 9.9E-02N2O emissions are negligibleEs,n= Ea,n* (459.67 + Ts) * Pa(459.67 + Ta) * PsEs,n= Natural gas volumetric emissions at standard temperature and pressure (STP) conditions in cubic feetEa,n= Natural Gas Volumetric Emissions at Actual Conditions in Cubic FeetTs= Temperature at standard conditions (°F)Ta= Temperature at actual emission conditions (°F)Ps= Absolute pressure at standard conditions (psia)Pa= Absolute pressure at actual conditions (psia)Masss,i= GHGi(either CH4or CO2) mass emissions at standard conditions in metric tons CO2eEs,i= GHGi(either CH4 or CO2) volumetric emissions at standard conditions in cubic feetPi= Density of GHGi. Use 0.0538 kg/ft3for CO2and N2O, and 0.0196 kg/ft3for CH4at 68°F and 14.7 psia or 0.0530 kg/ft3for CO2and N2O,and 0.0193 kg/ft3for CH4at 60°F and 14.7 psia.GWP= Global warming potential, 1 for CO2, 21 for CH4, and 310 for N2O8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, GHG - Flare Stacks9/30/2011Bakken Pool Oil and Gas Production FacilitiesAir Pollution Control Permitting & Compliance Guidance - May 2, 2011North Dakota Department of Health - Division of Air QualityDefault FactorsOil/Condensate Tank DataVapor Recovery Unitor Oil StabilizerEnclosed SmokelessCombustorUtility Flare or Other 98% DREDeviceGround Pit Flare or Other 90% DRE Device97.91 2000 45.19 79.8 2.26 99 98 98 90Control RequirementsIf first date of production occurred after June 1, 2011, tank emissions must be controlled by a ground it flare or other control device that achieves at least 90% DRE for VOCs upon startup of the facility.Facilities must calculate VOC PTE within 90 days after the first day of production.If PTE for VOC emissions is < 20 tpy, then a minimum of a ground pit flare (90% DRE) is required.If PTE for VOC emissions is > 20 tpy, then a control device that achieves at least 98% DRE must be installed and operated.Treater Gas DataEnclosed SmokelessCombustorUtility Flare or Other 98%DRE DeviceGround Pit Flare or Other90% DRE DeviceConnected to Sales Line98 98 90 100Control RequirementsTreater gas must be routed to a gas gathering pipeline as soon as practicable in accordance with North Dakota Industrial Commission Requirements.When a pipeline is not available, treater gas is required to be routed to a control system or device (appropriate devices are included in the table above).Treater Burner DataNOx CO VOCHAPS8,760100 84 5.5 1.89*Taken from AP-42, Tables 1.4-1, 1.4-2 and 1.4-3 - Emission Factors from Natural Gas Consumption. Based on average heating value of 1020 Btu/scf of natural gas.Truck Loading DataSubmerged Loading of aClean Cargo TankSubmerged Loading:Dedicated Normal ServiceSubmerged Loading:Dedicated VaporBalance ServiceOil is Hauled by Truck Oil is Sold through LACT 0.5 0.6 1Refer to Table 2 onTruck Loading tabRefer to Table 2 onTruck Loading tabIf no specific data, useestimated average annualtemperatureEmissions calculated using formula provided in AP-42.Saturation factors taken from AP-42, Table 5.2-1 - Saturation (S) Factors for Calculating Petroleum Liquid Loading Loss.P and M values taken from Table 7.1-2 - Properties of Selected Petroleum Liquids.Control RequirementsBakken Pool O&G production facilities are not required to route emissions displaced from truck loading activities to a controlsystem or device due to safety concerns.However, the owner/operator shall follow any operating and/or construction requirements established in Chapters 33-15-07 and 33-15-20 of the North Dakota Air Pollution Control Rules.Temperature of Bulk LiquidLoaded (°F)Hours of OperationNatural Gas Emission Factors* (lb/MMscf)Destruction Devices and Efficiency (%)Sales MethodMode of Operation and Appropriate Saturation FactorMolecular Weight ofTank Vapors(lb/lb-mole)Vapor Pressure ofLiquid Loaded(psia)Destruction Devices and Efficiency (%)Default Bakken EF(scf/bbl)Lower Heating Value ofTank Vapors(Btu/scf)Molecular Weight of TankVapors(lb/lb-mole)VOC Weight Fraction ofTank Vapor Gas (C3+) (%)HAP Weight Fractionof Tank Vapor Gas (%)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, NDDoH Default Factors 28 of 369/30/2011Bakken Pool Oil and Gas Production FacilitiesAir Pollution Control Permitting & Compliance Guidance - May 2, 2011North Dakota Department of Health - Division of Air QualityDefault FactorsPneumatic Pumps DataRouted Exhaust Back intoClosed Loop SystemRouted Exhaust to aCombustion Device4,380 100 98Control RequirementsBakken Pool O&G production facilities are required to control pneumatic pumps that use natural gas as the motive gas, if the PTE of VOCs from the pneumatic pump is > 5 tpy per pump.Pneumatic Controllers DataThere are not default factors for pneumatic controllers. Emissions are calculated based on the following: number of controllers, gas usage or bleed rate (scf/hr), VOC/HAP weight fraction, molecular weight and hours of operation.Control RequirementsBakken Pool O&G production facilities are not required to install add-on controls for emissions from these types of devices.Glycol Dehydrator DataVOC Emissions (tpy) HAP Emissions (tpy)0 0Use emissions calculated in GRI-GLYCalc V4 software; if no Glycol Dehydrator is installed, enter 0.RICE Engines DataHours of OperationNOx AP-42Emissions Factor(g/hp-hr)CO AP-42Emissions Factor(g/hp-hr)VOC AP-42Emissions Factor(g/hp-hr)NOx Control EfficiencyCO ControlEfficiencyVOC Control Efficiency8,760Manufacturer data, actualtest results orAP-42 emission factorsManufacturer data, actualtest results orAP-42 emission factorsManufacturer data, actualtest results orAP-42 emission factorsManufacturer data oractual test resultsManufacturer data oractual test resultsManufacturer data oractual test resultsWhile emission factors from actual stack testing, manufacturer's engine data, and AP-42 are acceptable, actual test data is usually the most accurate and preferred method.Control RequirementsNDDoH does not require any specific air pollution control equipment; however, the RICE must be in compliance with all State andFederal Rules and Regulations.See the Federal Rules and Regulations tab for specifics regarding applicable Federal Rules.Annual Hours of Operation -Winter Months OnlyControl Devices and Efficiency (%)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, NDDoH Default Factors 29 of 369/30/2011US EPAAP 42, Compilation of Air Pollutant Emission FactorsApplicable TablesOil/Condensate Tank and Treater Flare13.5-1 - Emission Factors for Flare OperationsTotal Hydrocarbonsb0.14Carbon Monoxide 0.37Nitrogen Oxides 0.068Sootc0 - 274bMeasured as methane equivalent.Treater Burner DataTable 1.4-1 - Emission Factors for Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from Natural Gas CombustionCombustor Type(MMBtu/hr Heat Input)NOxEmission Factor(lb/106scf)CO Emission Factor(lb/106scf)Uncontrolled (Pre-NSPS) 280 84Uncontrolled (Post-NSPS) 190 84Controlled - Low NOxBurners140 84Controlled - Flue Gas Recirculation 100 84Uncontrolled 100 84Controlled - Low NOxBurners50 84Controlled - Low NOxBurner /Flue Gas Recirculation32 84Uncontrolled 170 24Controlled - Flue Gas Recirculation 76 98Uncontrolled 94 40Units are in lb/MMscf of natural gas fired. To convert from lb/106scf to lb/MMBtu, divide by 1,020.Tangential-Fired Boilers (All Sizes)Residential Furnaces (< 0.3)ComponentEmission Factor(lb/106Btu)cSoot in concentration values: nonsmoking flares, 0 micrograms per liter (ug/l); lightlysmoking flares, 40 mg/l; average smoking flares, 177 ug/l; and heavy smoking flares, 274ug/l.Large Wall-Fired Boilers (>100)Small Boilers (< 100)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, AP-42 Tables 30 of 369/30/2011US EPAAP 42, Compilation of Air Pollutant Emission FactorsApplicable TablesTable 1.4-2 - Emission Factors for Criteria Pollutants and Greenhouse Gases from Natural Gas CombustionPollutantEmission Factor(lb/106scf)CO2120,000Lead0.0005N2O (Uncontrolled)2.2N2O (Controlled - Low NOxBurner)0.64PM (Total)7.6PM (Condensable)5.7PM (Filterable)1.9SO20.6TOC11Methane2.3VOC5.5PM is assumed to be less than 1.0 micrometer in diameter. Therefore, the PM emission factors may be used to estimate PM10and PM2.5.SO2is based on 100% conversion of fuel sulfur to SO2. Assumes sulfur content is natural gas of 2,000 grains/106scf.Table 1.4-3 - Emission Factors for Speciated Organic Compounds from Natural Gas CombustionEmission factors are included in the Natural Gas Combustion calculations.Truck LoadingTable 5.2-1 - Saturation (S) Factors for Calculating Petroleum Liquid Loading LossesCargo Carrier Mode of Operation S FactorSubmerged loading of aclean cargo tank0.50Submerged loading:dedicated normal service0.60Submerged loading:dedicated vapor balanceservice1.00Splash loading of a cleancargo tank1.45Splash loading: dedicatednormal service1.45Splash loading: dedicatedvapor balance service1.00Tank Trucks and Rail Tank Cars8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, AP-42 Tables 31 of 369/30/2011US EPAAP 42, Compilation of Air Pollutant Emission FactorsApplicable TablesTable 7.1-2 - Properties (MV, PVA, WL) of Selected Petroleum Liquids40°F 50°F 60°F 70°F 80°F 90°F 100°FCrude Oil RVP 5 50 7.1 1.8 2.3 2.8 3.4 4 4.8 5.7Distillate Fuel Oil No. 2 130 7.1 0.0031 0.0045 0.0065 0.0090 0.012 0.016 0.022Gasoline RVP 7 68 5.6 2.3 2.9 3.5 4.3 5.2 6.2 7.4Gasoline RVP 7.8 68 5.6 2.5929 3.2079 3.9363 4.793 5.7937 6.9552 8.2952Gasoline RVP 8.3 68 5.6 2.7888 3.444 4.2188 5.1284 6.1891 7.4184 8.8344Gasoline RVP 10 66 5.6 3.4 4.2 5.2 6.2 7.4 8.8 10.5Gasoline RVP 11.5 65 5.6 4.087 4.9997 6.069 7.3132 8.7519 10.4053 12.2949Gasoline RVP 13 62 5.6 4.7 5.7 6.9 8.3 9.9 11.7 13.8Gasoline RVP 13.5 62 5.6 4.932 6.0054 7.2573 8.7076 10.3774 12.2888 14.4646Gasoline RVP 15.0 60 5.6 5.5802 6.774 8.1621 9.7656 11.6067 13.7085 16.0948Jet Kerosene 130 7.0 0.0041 0.0060 0.0085 0.011 0.015 0.021 0.029Jet Naphtha (JP-4) 80 6.4 0.8 1 1.3 1.6 1.9 2.4 2.7Residual Oil No. 6 190 7.9 0.00002 0.00003 0.00004 0.00006 0.00009 0.00013 0.00019RICE Engines DataTable 3.3-1 - Emission Factors for Uncontrolled Gasoline and Diesel Industrial Engineslb/hp-hr(Power Output)lb/MMBtu(Fuel Input)lb/hp-hr(Power Output)lb/MMBtu(Fuel Input)NOx 0.011 1.63 0.031 4.41CO 6.96E-03 0.99 6.68E-03 0.95SOx 5.91E-04 0.084 2.05E-03 0.29PM10 7.21E-04 0.1 2.20E-03 0.32CO2 1.08 154 1.15 64Aldehydes 4.85E-04 0.07 4.63E-04 0.07TOC - Exhaust 0.015 2.1 2.47E-03 0.35TOC - Evaporative 6.61E-04 0.09 0.00 0.00TOC - Crankcase 4.85E-03 0.69 4.41E-05 0.01TOC - Refueling 1.08E-03 0.15 0.00 0.00Table 3.3-2 - Speciated Organic Compound Emission Factors for Uncontrolled Diesel EnginesEmission factors are included in the RICE calculations.True Vapor Pressure, PVA(psi)PollutantGasoline FuelEmission FactorsDiesel FuelEmission FactorsPetroleum LiquidVapor Molecular Weight @60°F, MV(lb/lb-mole)Liquid Density @60°F, WL(lb/gal)8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, AP-42 Tables 32 of 369/30/2011Federal Rules and Regulations Applicable to the Oil and Gas IndustryThis regulation document is provided by the North Dakota Department of Health for information purposes only.Please reference the rule for complete applicability and full details.40 CFR Part 60 - New Source Performance Standards (NSPS)Subpart Applicability and Description Subpart Reviewed for ApplicabilitySubpart IIII - Stationary Compression IgnitionInternal Combustion EnginesApplies to any compression ignition internal combustion engine where construction iscommenced after July 11, 2005 where the engine is manufactured after April 1, 2006NASubpart JJJJ - Stationary Spark Ignition InternalCombustion EnginesApplies to any spark ignition internal combustion engine where construction is commencedafter June 12, 2006 where the engine is manufactured:- After July 1, 2007 for engines > 500 hp- After July 1, 2008 for lean-burn engines 500 < hp < 1350- After July 1, 2008 for engines < 500 hp- After January 1, 2009 for emergency enginesonly 8 hp gasoline engine on siteSubpart GG - Stationary Gas TurbinesApplies to all stationary gas turbines with a heat input≥10 MMBtu/hr based on the lowerheating value of the fuel where construction is commenced after October 3, 1997 but beforeFebruary 18, 2005NASubpart KKKK - Stationary Combustion TurbinesApplies to stationary gas turbines with a heat input≥10 MMBtu/hr based on the higherheating value of the fuel where construction, modification or reconstruction is commencedafter February 18, 2005NASubpart Kb - Volatile Organic Liquid (VOL) StorageVessels (Including Petroleum Liquid StorageVessels) for which Construction, Reconstructionor Modification Commenced after July 23, 1984Applies to each storage vessel with a capacity of≥75 m3that is used to store VOL for whichconstruction, reconstruction, or modification commenced after July 23, 1984. Commonexceptions to this rule include:- Does not apply to storage vessels with a capacity > 151 m3storing a liquid with a maximumtrue vapor pressure less than 3.5 kilopascals (kPa)- Does not apply to vessels with a capacity of 75≥m3< 151 storing a liquid with a maximumtrue vapor pressure less than 15.0 kPa- Does not apply to vessels with a design capacity < 1,589.874 m3used for petroleum orcondensate stored, processed or treated prior to custody transferNA - prior to custody transferSubpart Dc - Small Industrial - Commercial -Institutional Steam Generating UnitsApplies to all steam generating units for which construction, modification or reconstruction iscommenced after June 9, 1989 and that has a maximum design capacity of 10≥MMBtu/hr <100NASubpart KKK - Equipment Leaks of VOC fromOnshore Natural Gas Processing PlantsApplies to affected facilities at onshore natural gas processing plants NASubpart LLL - Onshore Natural Gas Processing:SO2EmissionsApplies to each sweetening unit and each sweetening unit followed by a sulfur recovery unitat facilities that process natural gasNAExisting NSPS covers only natural gas processingplants and the proposal would cover additionalemission points including: well completions (andre-completions), compressors, pneumaticcontrollers, storage vessels (condensate andcrude oil tanks.EPA is under a consent decree deadline to takefinal action on these rules by February 28, 2012- Would limit VOC emissions from gas wells as they are being prepared for production, aprocess called "well completion".- Would apply to all hydraulically fractured (fracked) wells, both new wells and existing wellsthat are fracked or refracked to get more gas out of a well.- Would require combination of green completion and flaring for most fractured wells.Achieve 95% VOC reduction and 90% recovery of salable natural gas. Require flaring insituations not meeting criteria for reduced emissions completion where flaring is not ahazard.- Would require VOC reductions from other operations in the oil and gas sector including:-Compressors, which help move natural gas along a pipeline. Centrifugal and reciprocatingcompressors would be required to reduce VOC emissions.-Pneumatic Controllers, which regulate pressure, flow and temperature. Cover unitslocated at gas processing plants and compressor stations.-Storage Tanks, located at wells and other production facilities. Reduce VOC emissions by95%.-Onshore Natural Gas Processing Plants. Strengthen leak detection and repairrequirements of existing NSPS.NA - stil proposed*Based on the EPA document "Addressing Air Emissions from the Oil and Natural Gas Industry - Overview of EPA's Proposed New Source Performance Standards and NationalEmission Standards for Hazardous Air Pollutants".EPA Review - Natural Gas Processing Plants*EnginesTurbinesTanksHeatersNatural Gas Processing Plants*8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Federal Rules33 of 369/30/2011Federal Rules and Regulations Applicable to the Oil and Gas IndustryThis regulation document is provided by the North Dakota Department of Health for information purposes only.Please reference the rule for complete applicability and full details.40 CFR Part 63 - National Emission Standards for Hazardous Air Pollutants (MACT)Subpart Applicability and Description Subpart Reviewed for ApplicabilitySubpart ZZZZ - Stationary Reciprocating InternalCombustion EnginesApplies to any (new, existing, modified and reconstructed) reciprocating internal combustionengines located at a major source or area source of hazardous air pollutants (HAPs).only 8 hp gasoline engine on siteSubpart HH - Oil and Gas Production FacilitiesApplies to all oil and gas production facilities that are major and area sources of HAPs with thefollowing exceptions:- A facility that exclusively processes, stores or transfers black oil- A major source prior to the point of custody transfer with a facility-wide annual averagenatural gas throughput < 18.4 thousand cubic meters/day and a facility-wide annualhydrocarbon liquid throughput < 37,700 liters/day.The facility will be a synthetic minorsourceSubpart HHH - Natural Gas Transmission andStorage FacilitiesApplies to owners and operators of natural gas transmission and storage facilities thattransport or store natural gas prior to entering the pipeline to a local distribution company orto a final end user and that are major sources of HAP emissions.NAProposal for Air Toxics - Oil and Gas ProductionFacilities and Natural Gas Transmission andStorage Facilities*EPA is under a consent decree deadline to takefinal action on these rules by February 28, 2012Technology Review- No available cost-effective technologies for controlled glycol dehydrators and storage tanksthat could achieve greater reductions that current standards.- Standard for equipment leaks has been made more stringent.Review identified unregulated emission points, and proposal includes provisions to reduceemissions-Glycol Dehydrators- Establish limits for small dehydrators at major sources.-Storage Tanks(Oil and Gas Production Only) - Regulate all crude oil and condensate tanks atmajor sources. Remove throughput, API gravity and gas/oil ratio criteria.Risk Review- Rule proposes to reduce amount of air toxics allowed to be emitted.- Eliminate the 1 tpy benzene compliance option for glycol dehydrators at major sources (Oiland Gas Production and Natural Gas Transmission/Storage).NA - stil proposedEnginesProposal for Air Toxics - Oil and Gas Production Facilities and Natural Gas Transmission and Storage Facilities**Based on the EPA document "Addressing Air Emissions from the Oil and Natural Gas Industry - Overview of EPA's Proposed New Source Performance Standards and NationalEmission Standards for Hazardous Air Pollutants".Oil and Gas Production FacilitiesNatural Gas Transmission and Storage Facilities8Attachment 3 - Revised Maximum Production Rate with Gas Sales Calculation Sheet.xlsx, Federal Rules34 of 369/30/2011Average Casinghead Gas Analysis DataCompound FuelMW Wt Gross Grosslb/lb-mole lb Btu/scf Btu/scfoxygen n 0.000% 32.00 0.0000 0.00% 0 0.0nitrogen n 2.717% 28.013 0.7611 2.67% 0 0.0H2Sn 0.000% 34.076 0.0000 0.00% 637.1 0.0CO2n 1.115% 44.01 0.4909 1.73% 0 0.0C1 / CH4n 47.239% 16.043 7.5786 26.63% 1010.0 477.1C2 n 26.069% 30.07 7.8389 27.55% 1796.6 468.4C3 y 14.617% 44.10 6.4455 22.65% 2516.1 367.8C4, iso y 1.569% 58.12 0.9122 3.21% 3251.9 51.0C4, n y 3.766% 58.12 2.1888 7.69% 3262.3 122.9C5, iso y 0.594% 72.15 0.4289 1.51% 4000.9 23.8C5, n y 1.131% 72.15 0.8162 2.87% 4008.9 45.3C6+ y 1.182% 84.18 0.9953 3.50% 4755.9 56.2Totals100.00% 28.46 100.00% 1,612.5weight % VOC:41.42%Heating ValueComponent VOCMole2%Wt%

# (If speciated by lab, enter HAPs at bottom of sheet, not lumped with carbon numbers)

(enter composition in %, not mole fraction)

Gas Source: Average from 4 existing locations collected by Comm Engineering



# Sample Date: 05/28/09-06/05/09

Compound Gas



# Correction Mole % Net LHV

Mole % Calculations w/o air Mole Wt Wt Wt% Btu/scf Btu/scf

oxygen 0.000% 0.000% 0.000% 

# 32.00 0.0000 0.00% 

# 0 0.0

nitrogen 5.055% 5.055% 5.055% 

# 28.01 1.4161 3.21% 

# 0 0.0

hydrogen sulfide 0.000% 0.000% 0.000% 

# 34.08 0.0000 0.00% 

# 586.8 0.0

carbon dioxide 0.285% 0.285% 0.285% 

# 44.01 0.125 4 0.28% 

# 0 0.0

methane 7.242% 7.242% 7.242% 

# 16.04 1.1618 2.63% 

# 909.4 65.9

ethane 24.148% 24.148% 24.148% 

# 30.07 7.2613 16.46% 

# 1618.7 390.9

propane 33.425% 33.425% 33.425% 

# 44.10 14.739 4 33.41% 

# 2314.9 773.8

isobutane 4.619% 4.619% 4.619% 

# 58.12 2.6847 6.09% 

# 3000. 4 138.6

n-butane 15.573% 15.573% 15.573% 

# 58.12 9.0515 20.52% 

# 3010.8 468.9

isopentane 2.605% 2.605% 2.605% 

# 72.15 1.8795 4.26% 

# 3699.0 96.4

n-pentane 3.643% 3.643% 3.643% 

# 72.15 2.628 4 5.96% 

# 3706.9 135.0

n-hexane 0.736% 0.736% 0.736% 

# 86.18 0.6343 1.44% 

# 4403.8 32.4

hexanes, other 1.222% 1.222% 1.222% 

# 84.18 1.0287 2.33% 

# 4403.8 53.8

heptanes 0.987% 0.987% 0.987% 

# 100.21 0.9891 2.24% 

# 5100.0 50.3

octanes 0.035% 0.035% 0.035% 

# 114.23 0.0400 0.09% 

# 5796.1 2.0

nonanes 0.043% 0.043% 0.043% 

# 128.26 0.0552 0.13% 

# 6493.2 2.8

decanes plus 0.002% 0.002% 0.002% 

# 142.29 0.0028 0.01% 

# 7189.6 0.1

benzene 0.047% 0.047% 0.047% 

# 78.11 0.0367 0.08% 

# 3590.9 1.7

toluene 0.019% 0.019% 0.019% 

# 92.14 0.0175 0.04% 

# 4273.6 0.8

ethylbenzene 0.004% 0.004% 0.004% 

# 106.17 0.0042 0.01% 

# 4970.5 0.2

xylenes 0.006% 0.006% 0.006% 

# 106.17 0.006 4 0.01% 

# 4957 0.3

2,2,4-trimethylpentane 0.305% 0.305% 0.305% 

# 114.23 0.348 4 0.79% 

# 5738 17.5

(should total 100%) 

# 100.00% 100.00% 100.00% 44.11 

# 100.00% 2231.4

gas gravity 1.5229

gas rate, mscfd weight % VOC (C3+) 77.41% weight % HAPS 2.37%

mole % VOC 63.27% TANK VENT EMISSION CALCULATION

Marathon Oil Company

# Attachment 4

– Manufacturer Specifications