Independence Plaza

1050 17th Street, Suite 500

Denver, CO 80265

Tel 303 672 6900

- Fax 3032949632



### QEP Energy Company

Via e-mail to: r8airpermitling@epa.gov

December 23, 2011

US Environmental Protection Agency
Minor NSR Permitting Coordinator
U.S. EPA, Region 8
1595 Wynkoop Street, 8P-AR Denver, CO 80202-1129

Re: QEP Energy Company

Indian Country Minor Source Permit Application Facility Name: 4-35E

Fort Berthold Indian Reservation, North Dakota

Dear Sir or Madam:

As required by 40 CFR 49.154, attached please find a completed application for the abovereferenced facility. It is recommended for processing in the first group of applications, as discussed in recent meetings with EPA Region 8 representatives.

This facility is listed in Administrative Complaint and Consent Agreement (CA) Docket No. CAA-08-2011-026, Appendix A, Table A-4 (revised by letter from QEP Energy Company (QEPE) to EPA, dated October 14, 2011).

This application represents discussions and correspondence between representatives of QEPE,

the North Dakota Petroleum Council and EPA Region 8. QEPE has prepared this application to
reflect that communication and we greatly appreciate the efforts of, and guidance provide by

EPA.

If you have any questions concerning this application, please contact me.

### Si~eIY'

# ~4~/'- Daniel Ryan
Sr. Environmental Engineer

Cc: Randy Judge

Matt Thompson EPA via USPS

TAT

### UNITED STATES ENVIRONMENTAL PROTECTION AGENCY Region 8 Air Program

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY



## Check List

– Application for New Construction (Form NEW )

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



##  Proposed Construction of a New Facility



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



## o Proposed Modification of an Existing Facility



## o Other

– Please Explain

Use of this information request form is voluntary and not yet approved by the Office of Management and Budget. The following is a check list of the type of information that Region 8 will use to process information on your proposed project. While submittal of this fo rm 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 Manag ement 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 Permit ting Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P

- AR Denver, CO 80202

- 1129 The Tribal Environmental Contact for the specific reservation:

If you need assistance in identifying the appropriate Tribal Environmental Contact and address, please contact the EPA Region 8 Tribal Air Coordinator:

Alexis North, EPA Region 8 Tribal Air Coordinator

303

- 312

- 7005 north.alexis@epa.gov


### A. GENERAL FACILITY INFORMATION

1. (a) Company Name 

## QEP Energy Company

(b) Operator Name 2. Facility Name



## 4

- 35E Facility

3. Type of Operation 

## Oil & Gas Well Facility 4. Portable Source? Yes  No

5. Temporary Source? Yes  No

6 . NAICS Code 

## 211111 7 . SIC Code 

## 131101

8 . Physical Address (home base for portable sources)

9 . Reservation*


## Fort Berthold 1 0 . County*


## Dunn 1 1 a. Latitude* 

## 47.68672 1 1 b. Longitude*



## - 102.29754

1 2 a. Quarter Quarter Section *


## NWNW 1 2 b. Section* 

## 35 1 2 c. Township* 

## 149N 1 2 d. Range* 

## 91W

* Provide all proposed locations of operation for portable sources

### B. PREVIOUS PERMIT ACTI ONS (P rovide 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 

## NEW FACILITY

- NOT APPLICABLE

Permit Number (xx

- xxx

- xxxx x

- xx xx .xx)

Date of the Permit Action

Facility Name on the Permit 

## NEW FACILITY

- NOT APPLICABLE

Permit Number (xx

- xxx

- xxxxx

- xxxx.xx)

Date of the Permit Action

Facility Name on the Permit 

## NEW FACILITY

- NOT APPLICABLE

Permit Number (xx

- xxx

- xxxxx

- xxxx.xx)

Date of the Permit Action

Facility Name on the Permit 

## NEW FACILITY

- NOT APPLICABLE

Permit Number (xx

- xxx

- xxxxx

- xxxx.xx)

Date of the Permit Action

Facility Name on the Permit 

## NEW FACILITY

- NOT APPLICABLE

Permit Number (xx

- xxx

- xxxxx

- xxxx.xx)

Date of the Permit Action

### C . CONTACT INFORMATION
Company Contact 

## Dan Ryan Title 

## Sr. Environmental Eng ineer

Mailing Address 

## 1050 17th Street, Suite 500, Denver, CO 80265

Email Address 

## Dan.Ryan@qepres.com

Telep hone Number 

## (303) 672

- 6900 Facsimile Number 

## (303) 294

- 9632

Operator Contact (if different from company contact ) Title

Mailing Address

Email Address

Telephone Number Facsimile Number

Facility Contact 

## Dan Ryan Title 

## Sr. Environmental Eng ineer

Mailing Address 

## 1050 17th Street, Suite 500, Denver, CO 80265

Email Address 

## Dan.Ryan@qepres.com

Telephone Number 

## (303) 672

- 6900 Facsimile Number 

## (303) 294

- 9632

Compliance Contact 

## Dan Ryan Title 

## Sr. Environmental Eng ineer

Mailing Address 

## 1050 17th Street, Suite 500, Denver, CO 80265

Email Address 

## Dan.Ryan@qepres.com

Telephone Number 

## (303) 308

- 3070 Facsimile Number 

## (303) 294

- 9632

### D

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

 FORM SYNMIN

- New Source Review Synthetic Minor Limit Request Form, if synthetic minor limits are being requested.

 Narrative description of the proposed production proc esses. 

### This description should follow the flow of the process flow diagram to be submitted with this application.

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

 

### A list and descriptions of all proposed emission unit s 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 mate rials used or final product produced proposed to be used on a daily, annual and maximum hourly basis

.

 Proposed o perating schedule, including number of hours per day, number of days per week and number of weeks per year.

 A list and description of all proposed emission controls, control efficiencies, emission limits, and monitoring
for each emission unit and air pollution generating activity.

 Criteria Pollutant Emissions

- Estimates of Current Actual Emissions, Current Allowable Emissions, Post

Change Uncontrolled Emissions, and Post

- Change Allowable Emissions for the following air pollutants: particulate matter, PM 10 , PM 2.5 , sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compound (VOC), lead (Pb) and lead comp ounds, fluorides (gaseous and particulate), sulfuric acid mist (H 2 SO 4 ), hydrogen sulfide (H 2 S), total reduced sulfur (TRS) and reduced sulfur compounds, including all
calculations for the estimates.

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

 Modeling

– Air Quality Impact Analysis (AQIA)

 ESA (Endangered Species Act)

 NHPA (National Historic Preservation Act)

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.1

FORM SYNMIN

1. This facility proposes a limitation of Volatile Organic Compounds (VOC) through the use of an enclosed
flare or utility flare.
This limitation will reduce storage tank VOC emissions by 98% through the installation of a enclosed
flare or utility flare.

2. The enclosed flare or utility flare will be designed in accordace with 40 CFR 60.18 and should be
considered to achieve 98% destruction of VOC. No testing of the flare destruction efficiency is
anticipated.
The flare will be manually monitored by observing that the flare is burning during periodic visits to the facility.
Record keeping or reporting is not proposed unless required by permit.

3. The enclosed flare or utility flare will be designed in accordace with 40 CFR 60.18 and should be

considered to achieve 98% destruction of VOC.

4. Estimates of post emissions based on the use of the control are located in the summary table
labeled "controlled production Equipment Emissions" and calculations are shown in Attachment D.4.

5. Potential green house gas emissions (both pre and post control) are less than 100,000 TPY CO2e
but greater than 250 TPY on a mass basis.

Uncontrolled Volatile Organic Compound (VOC) emissions from this facility would be considered major

for Prevention of Significant Deterioration (PSD) and Part 71 (Title V) regulations, storage tank VOC
emissions are controlled by utility flare to make this facility a synthetic monor for both PSD and Title V.

### UNITED STATES ENVIRONMENTAL PROTECTION AGENCY Region 8 Air Program

FEDERAL MINOR NEW SOURCE REVIEW PROGRAM IN INDIAN COUNTRY



## Checklist

- Synthetic Minor Limit Request ( Form SYNMIN )

Use of this information request form is voluntary and not yet approved by the Office of Management and Budget. The following is a check list 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 rev iew is completed.

Please submit information to following two entities :

Federal Minor NSR Permit Coordinator U.S. EPA, Region 8 1595 Wynkoop Avenue, 8P

- AR Denver, CO 80202

- 1129 The Tribal Environmental Contact for the specific reservation:

If you need assistance in identifying the appropriate Tribal Environmental Contact and address, please contact the EPA Region 8 Tribal Air Coordinator:

Alexis North, EPA Region 8 Tribal Air Coordinator

303

- 312

- 7005 north.alexis@epa.gov



### A. GENERAL INFORMATION
Company Name 

## QEP Energy Company Facility Name 

## 4

- 35E Facility

Company Contact or Owner Name 

## Dan Ryan Title 

## Sr. Environmental Eng ineer
Mailing Address 

## 1050 17th Street, Suite 500, Denver, CO 80265

Email Address 

## Dan.Ryan@qepres.com
Telep hone Number 

## (303) 308

- 3070 Facsimile Number 

## (303) 294

- 9632

B. ATTACHMENTS

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

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

 Item 1

- The proposed limitation and a description of its effect on current actual, allowable and the poten tial 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 Green h ouse Gas (GHG) pollutants before and after proposed

emission controls

.

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.1 Part B

Additional Compliance Information1 

## Attachment D.1.B to Application for Facility: _4-35E_ :

Proposed Permit Section Language and Additional Compliance Information

Requested Full Section I.E of permit:



### I. E. Control System Options and Requirements for VOC (or VOC and HAP) Emissions

1. Closed-Vent Systems

(a) Closed-vent systems (CVS) shall be used to route all VOC (or VOC and HAP) emissions from the VOC emitting devices to the control devices required by this permit.

(b) All components making up the CVS (lines, connections, fittings, valves, relief valves, or any other appurtenance employed to contain and collect gases, vapors, and fumes and transport them to control the VOC (or VOC and total HAP) control equipment) shall be maintained and operated during any time the control equipment is operating.

(c) Each closed-vent system shall be designed and operated with no visible emissions.

(d) If any closed-vent system contains one or more bypass devices that could be used to divert all or a portion of the gases, vapors, or fumes from entering the equipment to control devices required by this permit, the permittee shall meet the one of following requirements for each bypass device:

i. At the inlet to the bypass device that could divert the stream away from the

enclosed combustor to the atmosphere, properly install, calibrate, maintain, and operate a flow indicator that is capable of taking periodic readings and sounding an alarm when the bypass device is open such that the stream is being, or could be, diverted away from the control device to the atmosphere; or

ii. Label the bypass device valve installed at the inlet to indicate that the nondiverting position is the correct position for normal operation and that the valve should only be switched to the divert po sition in an emergency or other malfunction

situation.

2. Enclosed Combustors and Utility Flares

(a) Each enclosed combustor shall be designed to have sufficient capacity to achieve at least 98.0% destruction efficiency for the anticipated minimum and maximum hydrocarbon

volumetric flow rate and BTU content routed to the device.

(b) Each utility flare shall be designed and operated in accordance with the requirements of 40 CFR 60.18 and 40 CFR 63.11 and have sufficient capacity to achieve at least a 98.0% destruction efficiency for the minimum and maximum hydrocarbon volumetric flow rate and BTU content

routed to the device.

[Note: “Maximum” means instantaneous peak, i.e., the flash emissions resulting from

a liquid dump event upstream of the tank into which the liquid is dumping.]2 (c) E n c l o s e d c om bus t o r s a nd ut i li t y f l a r e s s h a l l b e o p e r a t e d :

i. At all times t h a t VOC e m i ss i o ns a r e r o u t e d t o it ; ii. Operated with a liquid knock out box to collect condensable vapors (to prevent form going through to the control device;
iii. Equipped with one or more of the following :

a. a t h e r mo c o up l e and continuous recording device s u c h a s a c h ar t r ec o r d e r , d a t a l o g g e r o r s i m il a r d e v i c e , t o d o c um e nt t h e p re s e n c e o f a pilot f l a me; with alarm; or
b. a visual site glass t o d e t e c t t h e p re s e n c e o f a p il o t f l a m e; or

c. a gas/vapor flow detector and auto igniter which lights the combustor burner or pilot burner when flow is detected ;

iv. M a i n t a i n e d i n a l e a k

- f r e e c o nd iti o n; a nd

v. Op e r a t e d i n a s mok e l e ss m o d e

.

( d) The p e r m itt e e s h a l l mo n i t o r t h e u ti l i t y f l a r e a nd e n c l o s e d c om bus t o r o p era tio ns t o

c o n f i r m p r o p e r o p e r a ti o n a s f o ll ows:

i. If using a thermo

- couple/recording device/alarm, c o n ti nu o us l y m o n it o r t h e p il o t f l a m e and respond to any alarms; c h e c k t he t h e r mo c o up l e a nd re c o r d i ng d e v i c e a nd t h e

p il o t f l a m e s t o i ns u r e p r o p e r o p era ti o n , quarterly a t a m i n i m u m

. ii. If using a visual site glass, visually check for the presence of a pilot flame, during routine operations and at least quarterly.
iii. If using a gas/vapor flow detector and auto igniter, check the system proper operation during routine operations and at least quarterly.

ii i

. V i su a l l y c o n f i r m t h a t no s m o k e i s p r e s e nt d u

r i ng o p era ti o n o f a n y e n c l o s e d

c om bus t o r o r util i t y f l ar e , during routine operations and at least quarterly.

3. Pi t F l are s

( a ) A p i t f l a r e may be u s e d f o r t h e f o ll o w i n g o p er a ti o ns:

i

. To c o n t r o l e m i ss i o ns d u

r i ng w e l l c om p l e ti o ns a nd r e

- c om p l e ti o ns; ii

. To c o n t r o l e m i ss i o ns i n t he e v e nt t h e p r o du ce d h y d r o c a r b o n g a s t h a t i s b e i ng

r e c ov ere d f o r s a l e o r o t h e r b e n e f i c i a l p u r p o se m ust b e d i v er t e d t o a n e m e r g e n c y

c o n t r o l d e v i c e a nd no uti l i t y f l a

r e i s c u r re n t l y i ns t a ll e d o r o p e r a ti ng a t t h e fa c ili t y f o r

a n y pu r p o s e ; iii. To c o n t r o l e m i ss i o ns i n t he e v e nt t h e VOC ( o r V OC a nd H A P ) e m i ss i o ns t h a t a r e b e i ng

r e c ov ere d f r o m e m i ss i o n un it s f o r s a l e o r o t h e r b e n ef i c i a l p u r p o se m ust b e d i v er t e d t o a n

e m er g e n c y c o n t r o l d e v i c e due t o s u dd e n , i n f r e qu e nt

, a nd u n a v o i d a b l e e v e n t s , a nd

e n c l o s e d c o m bus t o r s h a v e n o t b e e n i n s t a l l e d a t t h e f a c ili t y f o r t h e pu r p o se o f c o n t r o lli ng VOC ( o r VOC a nd H A P ) e m i ss i o ns fr o m a n y un it s a t t h e f a c i l i t y ; or iv. Within the first 90 days after the first date of production, as specified under Section I.D.2(b),(c)

( b) The p e r m itt e e s h a l l o n l y use t h e p i t f l ar e und e r t h e f o ll o w i n g c o nd iti o ns a n d li m i t a ti o ns:

i

. The p i t f l ar e i s o p e r a t e d w it h a t l e a st a 9 0

. 0 % d e s t r u c ti o n ef f i c i e n c y ; a nd

ii

. The f a c ili t y

- w i de VOC ( o r VO C

, t o t a l H A P

, a nd e a c h i nd i v i du a l H A P ) i s n o t

e x c ee d e d; a nd3 iii. Use o f t h e p i t f l a r e i s li m it e d t o no mo r e t h a n 900 h o u r s i n a n y January 1

– December 31 calendar year; and

iv. The 90 day initial production period of allowed pit flare operation ( Sections I.D.2(b),(c)) is
not included in the 900 hour per year limit for pit flare operation.

v. A d e mo ns t ra t i o n o f c o m p li a n c e w it h t he h o u r s o f o p era ti o n li m i t i s m a de b y k ee p i ng log entry records du r i ng ea c h p e r i o d o f ti m e t h a t t h e p i t f l a r e i s o p era ti n g

. T h e

r e c o r ds s h a l l b e k e pt o ns i t e a t t he s o u rc e a nd sh a l l c o n t a i n t he f o ll o w i n g i n f o r m a ti o n:

( A ) D a t e a nd ti m e t h e f l ar e w a s s t a r t e d up a nd subs e q u e n t l y shut d o wn; ( B ) R unn i ng t o t a l o f t he h o u r s o p e r a t e d f o r t h e p re v i o us c o ns ec u ti v e 12 mo n t h s; and ( C ) B r i e f d e s c r i p ti o n o f t h e j us ti f i c a ti o n f o r o p e r a ti o n;

vi. The p i t f l ar e i s v i su a l l y i nsp e c t e d d a i l y , or at an appropriate frequency determined by the permittee, f o r proper operation (presence of pilot flame or other indicator) d u

r i ng it s us e

. If improper operation is observed it shall be corrected as soon a s p r a c t i ca b l e ; a nd

v i

. The p e r m itt e e s h a l l n o t d e p o s i t o r c a u s e t o b e d e po s it e d i n t o a f l a r e p i t a n y o i l f i e l d

f l u i ds o r o i l a nd g a s w a s t e s o t h e r t h a n t h o se d e s i g n e d t o g o t o t he p i t f l a re

.

4. O t h e r C o n t r o l D e v i c e s

C o n t r o l d e v i c e s o t h e r t h a n t h o se li s t e d a b ov e t h a t a r e ca p a b l e o f ac h i e v i ng 98

. 0 % d e s t r u c ti o n

e f

f i c i e n c y m a y be u ti l i ze d

, as specified in this permit or immediately after the permittee notifies EPA, subject to the requirements of Section II of this permit.

5. R e c o r d k ee p i ng R e qu i re m e n t s

( a ) Re c o r ds s h a l l b e k e pt o f a l l re q u i r e d t e s ti ng a nd mo n i t o r i ng o f t h e c o n t r o l d e v i c e

o p era ti o ns.

( b) R e c o r ds s h a l l b e k e pt o f a n y i ns t a n ce s i n wh i c h a n y c l o s e d

- v e nt s y s t e m o r c o n t r o l d e v i c e

w a s b y p a ss e d o r d o wn i n e a c h c a l e nd a r mo n t h, t h e re a s o n f o r e a c h i n c i d e n t

, i t s du r a ti o n,

a nd t he c o r re c ti v e a c ti o ns t a k e n o r t h e p re v e n t a ti v e m ea s u r e s a d o p t e d t o a vo i d su c h
b y p a ss e s o r d o wn ti m e s.

( c ) R e c o r ds s h a l l b e k e pt o f a n y i ns t a n ce s i n wh i c h t h e p il o t f l a m e or auto igniter system (ATS) i s n o t operating i n t he e n c l o s e d c om bus t o r o r t h e u til i t y f l a re , t he d a t e a n d ti m e s

t h a t t he p i l o t or ATS w a s n o t operating, a nd t he c o r r e c ti v e a c ti o ns t a k e n o r t he

p re v e n t a ti v e m e a su r e s a d o p t e d t o restore operation.

( d) R e c o r ds s h a l l b e k e pt o f a n y i ns t a n ce s i n wh i c h t h e t h e r mo c o up l e ( o r o t h e r h ea t s e ns i ng

m o n it o r i ng d e v i ce ) i n s t a l l e d t o d e t e c t t he p re s e n c e o f a f l a m e i n t h e e n c l o s e d c om bus t o r

o r u tili t y f l a r e i s n o t o p e r a t io n a l

, t h e ti m e p e r i o d d u

r i ng wh i c h i t w a s n o t o p e r a ti o n a l

, a nd

t he a nd t he c o r re c ti v e m ea s u re s t a k e n

.

( e ) R e c o r ds s h a l l b e k e pt o f a n y i ns t a n ce s i n wh i c h t h e re c o r d i ng d e v i c e i ns t a l l e d t o

r e c o r d d a t a f r o m t he t h er mo c o u p l e i s n o t o p e ra t i o n a l

.

( f

) R e c o r ds s h a l l b e k e pt o f a n y t i m e p e r i o ds i n wh i c h v i s i b l e e m i ss i o ns ar e

o bs er v e d e m a n a ti ng f r o m a c o n t r o l s y s t e m

.4 Requested Full Section I.F. of permit :

I. F. Equipment Leaks

– VOC (or VOC & HAP)

1. W o r k P r a c t i c e and Op e r a ti o n a l R e qu i r e m e n t s

( a ) The p e r m itt e e s h a l l m i n im i z e l e a k s o f vo l a til e o r g a n i c s f r o m e a c h p i e c e o f e qu i p m e nt i n h y d r o car b o n s e r v i c e a t t h i s f ac i li t y.

b) The p e r m itt e e s h a l l monitor and r e p a i r l e a k s a t vent li n es , f l a n g es , c o nn ec t i o ns, f i t ti n gs , o r

o t h e r devices e m p lo ye d t o c o n t a i n, c o ll ec t or convey g a s e s and vapors at the facility. Such monitoring and repair shall be performed at least quarterly m i n i m u m

.

( c ) A n y l ea k i n g e qu i p m e nt s h a l l b e r e p a i r e d a s s oo n a s p r a c t i c a b l e , a f t e r t he l e a k i s i n i ti a l l y d e t e c t e d

, un l e ss t h e r e p a i r i s t ec h n i c a l l y i n fea s i b l e w it h o ut a f a c i l i t y shu t d own.

( d) The p e r m itt e e s h a l l m a k e t h e f i rst a tt e m pt t o re p a i r a n y l ea k i n g e qu i p m e nt w it h i n f i v e d a y s a f t e r t h e l e a k i s d e t e c t e d

.

( e ) A n y l ea k i n g e qu i p m e nt s h a l l b e r e p a i r e d a s s oo n a s p r a c t i c a b l e , b u t no l a t e r t h a n 15 d a y s

a f

t e r t h e l e a k i s i n it i a l l y d e t e c t e d

, un l e ss t h e r e p a i r i s t ec h n i c a l l y i n fea s i b l e w it h o ut a f a c i l i t y shu t d o wn, parts are not available locally, or specialty repair is required. Su c h

e qu i p m e nt s h a l l b e re p a i r e d b ef o re t he e nd o f t h e f i rst f ac i li t y shu t d o wn a f t e r t h e l ea k i s i n it i a l l y d e t ec t e d

.

2. M o n i t o r i ng R e q u i r e m e nts

(a) The p e r m itt ee’s quarterly e qu i p m e nt l e a k detection p r o t o c o l consists of:

• A qualified permittee representative, who is familiar with the facility equipment, visits the facility on foot and uses audio, visual and olfactory observations (AVO) to check for leaks;

• An y e m i ss i o ns d e t e c t e d und e r t he p r o t o c o l a re defined as a l ea k un l e ss s c r e e n e d w i t h

M e t h o d 21 ( 40 C F R P a r t 6 0

, App e nd i x A

- 7) mo n it o r i n g , i n wh i c h ca s e , 1 0

, 000 ppm

o r g rea t e r i s d e s i g n a t e d a s a l e a k

.

• A l l l e a k d e t e c ti o n i ns p e c t i o n r ec o r ds s h a l l i n c l u d e , a t a m i n i m u m , t he f o ll ow i ng i n f o r m a ti o n:

 The d a t e and time o f t he i nsp e c ti o n;

 A l l d o c u m e n t a ti o n a n d / o r i m a g e s p r o du ce d i n t he i nsp e c ti o n;

 Location of any leaks and specific equipment involved;

 Quantification of leaks or suspected leaks using optional Method 21, if performed;

 A n y c o rr e c ti v e ac t i o n t a k e n or any first attempt to repair made; a nd the outcome of such attempts

 The i nsp e c t o r ' s n a m e a nd s i g n a t u r e

.



### 3. Recordkeeping requirements

The permittee shall maintain the records from the above leak detection and repair inspections . Those records shall be used to demonstrate that all leaks detected are repaired within5 the timeframes and other requirements specified in the above protocol.



### Requested Full Section I. H. of example permit :

I. H

. R e qu i r e m e n t s f or H y d r o c a r b on S t o r a ge T a nk s

1. H y d r o car b o n s t o ra g e t a nk s (HSTs) i n c l u d e t a n k s t h a t s t o r e h y d r o car b o n p r o du c t s a nd

h y d r o car b o n p r o du c ti o n w a s t e s t r ea m s s u c h a s , o i l p r o du c t i o n t a n k s; c o nd e ns a t e p r o du c t i o ns

t a n k s; and slop oil tanks. Produced water tanks at this facility are considered to be HSTs only if they are connected by piping, or by interconnected or common vent lines to other HSTs.

2. The p e r m itt e e s h a l l i n s t a l l

, m a i n t a i n , a nd o p e r a t e e ac h h y d r o car b o n s t o ra g e t a nk s u c h t h a t t he

l o n g

- t er m fa c ili t y

- w i de e m i ss i o n li m i t re qu i r e m e n t s i n t h i s p er m i t w il l b e m e t wh e n t he t o t a l

e m i ss i o ns f r o m t he t a n k s a r e i n c l u d e d i n t h e c o ns e c u ti v e 12

- mo n t h fa c il i t y

- w i de t o t a l

. Th i s

s h a l l be a c h i e v e d b y m ee ti ng o ne o r mo r e o f t he f o ll o w i ng e m i ss i o n c o n t r o l t e c h n i qu e s:

( a ) L i m i t t h e o p er a ti o n a l t h r o u g hput o f t h e t a n k s c o ns t r u c t e d a nd o p e r a t e d a t t he fa c ili t y ;

a nd / o r

( b) Use a c o n t r o l d e v i c e o p e r a t e d a s s p e c i f i e d b y t h i s p er m it ; a nd / o r

( c ) Use e qu i p m e nt d e s i g n e d t o ca p t u r e t h e VOC ( o r V OC a nd t o t a l H A P ) e m i s s i o ns f o r s a l e

o r o t h e r b e n e f i c i a l p u r p o s e

.

3. F o r e a c h h y d r o car b o n s t o ra g e t a nk w it h t h e p o t e n t i a l f o r f l a sh e m i ss i o ns, t h e p e r m itt e e s h a l l p e r f o r m

t h e f o ll o w i ng i nsp e c ti o ns a nd a n y n ece s s a r y re p a i r s o n a qu a r t e r l y b a s i s:

( a ) Check t h a t t h i e f h a t c h c ov er s a r e w e i g h t e d a nd p r o p er l y s ea t e d a nd t h e g a sk e t s a r e i n g o o d

c o nd iti o n t o p r e v e nt v e n ti ng o f e m i ss i o ns;

( b) Check t h a t p r e ssu r e r e li e f v a l v e s ( PR V) a r e s e t t o r e l e a se a t a p re ss u r e t h a t w il l e ns u r e f l a sh i n g , a nd s t a n d i n g / w o r k i n g / b rea t h i ng l o ss e s a r e r o u t e d t o a n e m i ss i o ns c o n t r o l d e v i c e

a s sp e c i f i e d i n t h i s p e r m it

, un d e r n o r m a l o p e ra t i ng c o nd iti o ns, i n c l u d i ng t he m a x i m um i ns t a n t a n e o us f il l ra t e t h a t m a y o cc ur d u

r i ng li qu i d du m

p i ng e v e n t s b y ups t rea m v e s s e l s

.

4. The p e r m itt e e s h a l l d o c um e nt a nd m a i n t a i n a r ec o r d o f t he q u a r t e r l y i nsp e c ti o ns. A l l i ns p ec t i o n

r e c o r ds sh a l l i n c l ud e , a t a m i n i m u m , t h e f o ll o w i n g i n f o r m a ti o n:

( a ) The d a t e o f t he i nsp e c ti o n;

( b) The f i n d i n g s o f t he i n sp e c ti o n;

( c ) A n y re qu i r e d r e p a i r s ; a n d

( d) The i nsp e c t o r ' s n a m e a nd s i g n a t u r e

.

5. The p e r m itt e e s h a l l f o ll ow, f o r e a c h s t o r a g e t a n k

, t he m a nu fa c t u re r ’ s r ec o m m e nd e d

m a i n t e n a n c e s c h e d u l e a nd o p e r a ti ng p r o ce d u

re s t o e ns u r e g o o d a i r p o ll u ti o n c o n t r o l p r ac ti c e s f o r m i n i m i z i ng e m i ss i o ns.6 6. R e c o r ds s h a l l b e k e pt o f a l l s c h e du l e d m a i n t e n a n c e a nd r e p a i r s

.

7. R e c o r ds s h a l l b e k e pt o f t he e m i ss i o ns c a l c u l a ti o ns i n c l u d e d i n t h e c o ns e c u t iv e 12

- mo n t h

fa c ili t y

- w i de t o t a l

.

(Requested additional paragraph to Section I.D.3.(a):

I.D.3.(a) Facility

– Wide Emission Requirements, Monitoring Requirements

“The permittee shall calculate monthly emission for each emission source type (tank s , process devices, etc.) using the ratio of: actual production throughput, operating hours, or other appropriate parameter, divided by the appropriate production parameter value used to calculate the estimated monthly emissions in the permit application. Th e emission ratio thus derived will be multiplied by emission value calculated for each source type in the application

, to determine the calculated emissions for each month

for each source type. “

R equested revised Section I.K.3. :

I.K.3. Requirements for Testing Engines over 500 horsepower

F o r e a c h e n g i ne w i t h a s i t e

- r a t e d bhp g r e a t e r t h a n o r e q u a l t o 50 0

, t he p er m itt e e s h a l l c o ndu c t an initial

E P A R e f er e n c e M e t h o d p er f o r m a n c e t e s t within one year of startup, m ea su r e VOC e m i ss i o ns. T h e

p e r m itt e e s h a l l a l so c o ndu c t sub s e q u e nt p e r f o r m a n c e t e s t s o n e ac h e n g i ne thereafter, e v e r y 8

, 760 h o u r s o f

o p e r a ti o n o r 3 y e ar s, wh i c h e v e r c om e s f i r s t

. T h e r e su l t s o f t he p e rf o r m a n c e t e s t s s h a l l b e u s e d t o

ca l c u l a t e t he actual e n g i ne e m i ss i o ns i n c l u d e d i n t h e c o ns ec u ti v e 1 2

- m o n t h f a c ili t y

- w i de t o t a l

.

R equested revised Section I.K.4

. :

I.K.4. Requirements for Catalyst

- Equipped Engines

F o r e a c h e n g i ne over 500 site

- rated horsepower, if equipped with a c a t a l y ti c c o n t r o l s y s t e m:

( a ) I ns t a ll

, o p e r a t e , a nd m a i n t a i n p re s su re

- s e ns i ng d e v i c e s a t t he i n l e t a nd o u tl e t o f t h e c a t a l y st t o

m ea su r e a nd re c o r d t h e p r e ss u r e d r o p a c r o ss t h e c a t a l y s t

.

( b) I ns t a ll

, o p e r a t e , a nd m a i n t a i n t e m p e r a t u r e

- s e ns i ng d e v i ce s t o m e a s u r e t h e t e m p era t u

r e o f t he

e n g i ne e xh a u st a t t he i n l e t o f t h e c a t a l y s t

.

( c ) M ea s u r e a nd r ec o r d t h e p re ss u r e d r o p a cr o ss t he c a t a l y st a nd t he t e m p e r a t u r e o f t h e e n g i ne

e xh a u s t a t t he i n l e t o f t h e ca t a l y st, at least monthly, to e ns u r e t h a t the pressure drop a nd

t e m p e r a t u r e a r e m a i n t a i n e d w it h i n t h e o p e r a ti ng li m it s s p e c i f i e d b y t he c a t a l y st m a nu f a c t u r e r

.

Other Requested Changes Revisions :

Other r equested changes to permit language include additional items not discussed above, but which

were listed or requested under “Technical Clarifications” in a letter f rom the North Dakota Petroleum Council to Mr. Jim Martin, E PA, dated December 7, 2011.

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.2

Process Description, Plot Plan, Process Flow Diagram and Site Location

Prepared for: Prepared by:

QEP Energy Company Lesair Environmental, Inc.

www.Lesair.comQEP Energy Company
Fort Berthold
4

- 35E Facility 

### Process Description

This is a multi

- well facility th at will separate production from five ( 5 ) proposed condensate and natural gas exploration and production w e lls drilled at this location

. Each well will flow to its respective process equipment; this equipment is similar in construction and function

. T he typical pro cess train is described below.

The commingled fluid stream (containing condensate , natural gas and produced water) flows from each well. The well fluids flow to its respective 6' x 20' vertical heater treater (0.5 MMBtu/hr burner duty rating). In this vertical treater, the fluid is heated to a desired temperature range to aid in separation of the c ondensate , natural gas and produced water.
Th e hydrocarbon liquid (condensate ) and produced water flow to their respective storage
tanks.

The natural gas stream from the vertical heater treater is expected to be metered into a natural gas sales pipeline. If the pipeline is not immediately available or if it becomes unavailable the natural gas will go to a utility flare.

From the condensate storage tanks, t he condensate will initially be sold into tanker trucks and
hauled from location. It is proposed th at a condensate sales pipeline will be installed in the future. Once installed, the condensate will be metered through a L.A.C.T. (Lease Automate d Custody Transfer) unit and sold as it is pumped, using electric motor driven pumps, into a
condensate sales p ipeline. If the condensate does not meet sales quality standards it is automatically diverted to one of the "divert" tank s where it will be treated until it can meet sales specifications and be sold.

The produced water will initially be hauled from locat ion using tanker trucks. Once a produced water pipeline is available an electric m otor driven water transfer pump will pump the produced water to a centralized water handling facility for disposal.

The hydrocarbon vapors from all of the storage tanks are sent to a utility flare through a common tank piping system.

There are fugitive emissions associated with the piping co nnections, flanges, valves , etc

. These emissions occur due to the potential seeping of gas from connections, seats, and seals

.

A trailer mounted dual fueled (diesel and natural gas) engine driven generator will be utilized for facility power until utility power is available. This generator will supply the power necessary to operate the LACT pumps

, a n electric motor driven pumping u nit, and other facility power
needs.

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### LEGEND

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# LMJ Meter 

### QEP Energy

WIll at.: 4_"l"lF F

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•. 47.68672N·**~_ME;** l.DngIIId.: -102.29754W.**-"'"~**

, Crul"" Plot Plan
NOT TO SCALE

0

.. : 12/104J2011**,.-,~:** Chris DiMIIfal



# --

AppIlMd By.

## N 4

- 35E Facility Topographic Map

QEP Energy Company Dunn County, North Dakota

Latitude: 47. 68672 N Longitude:

- 102. 29754 W

Drawn by: MAC

Date: December 2011 4

- 35E Facility

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.3

Facility Emissions Summary

Prepared for: Prepared by:

QEP Energy Company Lesair Environmental, Inc.

www.Lesair.comCompany Name:QEP Energy CompanyFacility Name:4-35E FacilityNOx CO SO2 ParticulatesVOC Total HAPsRef No. Equipment Note lb/hrTPY lb/hrTPY lb/hrTPY lb/hrTPY lb/hrTPY lb/hrTPY001 (5) 400 bbl. Condensate Storage Tanks a 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 511.44 2240.10 5.01 21.94002 (5) 400 bbl. Divert Tanks b 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00003 (4) 400 bbl. Produced Water Tanks c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00004 (1) 0.5 MMBtu/hr Heater Treater d, e 0.07 0.30 0.06 0.25 0.00 0.00 0.01 0.02 466.95 2045.22 10.86 47.59005 (1) 0.5 MMBtu/hr Heater Treater d, e 0.07 0.30 0.06 0.25 0.00 0.00 0.01 0.02 466.95 2045.22 10.86 47.59006 (1) 400 hp Generator f 4.23 18.52 2.29 10.03 0.82 3.59 0.13 0.58 0.88 3.86 0.00 0.00007 (1) 400 hp Generator f 4.23 18.52 2.29 10.03 0.82 3.59 0.13 0.58 0.88 3.86 0.00 0.00008 Truck Loading g 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 41.28 0.00 0.71009 Fugitives h 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.42 1.84 0.00 0.00Total 8.60 37.654.70 20.58 1.647.19 0.27 1.20 1447.51 6381.3927.48 117.82NOTES:a - Condensate tanks emissions estimated using the process simulation software BR&E ProMAX and a like kind pressurized condensate analysis (Rupple).b - Divert tanks are used only during upset conditions (i.e., when condensate does not meet sales specifications), quantification of emissions is not required.c - Produced water tank vent lines are connected to the condensate tank vent system and accounted for at source (001) "Condensate Storage Tanks". Produced water is notan emission source but the small amount of condensate that carries over in the water is the source of emissions, condensate tank emissions account for all of these emissions.d - Burner emissions based on EPA AP-42 emission factors from Section 1.4, Tables 1.4-1 and 1.4-2 for uncontrolled natural gasburners (July 1998), the worst case assumptionthat burners operate 8,760 hours per year and a fuel heating value of 1430 Btu/SCF.e - Heater Treater uncontrolled vent (casing head gas) VOC and HAP emissions represent a worst-case scenerio in which casing head gas does not go to pipeline.f - Generator engine emissions are estimated using 400 Hp diesel fueled tier II engine emission factors. These engines are trailer mounted and are expected to be portable.Engine emissions have been listed here to ensure that all emissions sources have been identified due to uncertainty of when utility power will be available.g - Truck loadout emissions were based on worst case assumption that produced liquids will be trucked from the facility year round, due to uncertainty of pipeline.h - Fugitive component type and count is an estimate, the emissions were calculated using EPA Table 2-4 for E&P production facilities.EPA Region 8 Minor Source Permitting ProgramUncontrolled Production Equipment EmissionsLesair Environmental, Inc.www.lesair.comCompany Name:QEP Energy CompanyFacility Name:4-35E FacilityEPA Region 8 Minor Source Permitting ProgramNOx CO SO2 ParticulatesVOC Total HAPsRef No. Equipment Note lb/hrTPY lb/hrTPY lb/hrTPY lb/hrTPY lb/hrTPY lb/hrTPY001 (5) 400 bbl. Condensate Storage Tanks a 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00002 (5) 400 bbl. Divert Tanks b 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00003 (4) 400 bbl. Produced Water Tanks c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00004 (1) 0.5 MMBtu/hr Heater Treater d,e 0.07 0.30 0.06 0.25 0.00 0.00 0.01 0.02 0.00 0.02 0.00 0.00005 (1) 0.5 MMBtu/hr Heater Treater d,e 0.07 0.30 0.06 0.25 0.00 0.00 0.01 0.02 0.00 0.02 0.00 0.00006 (1) 400 hp Generator f 4.23 18.52 2.29 10.03 0.82 3.59 0.13 0.58 0.88 3.86 0.00 0.00007 (1) 400 hp Generator f 4.23 18.52 2.29 10.03 0.82 3.59 0.13 0.58 0.88 3.86 0.00 0.00008 Truck Loading g 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 41.28 0.00 0.71009 Fugitives h 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.42 1.84 0.00 0.00010 Enclosed Flare or UtilityFlarei 6.76 29.61 13.50 59.11 0.00 0.00 0.00 0.00 28.92 126.69 0.54 2.34Total 15.36 67.26 18.19 79.69 1.647.19 0.27 1.20 31.11 177.561.27 3.05NOTES:a - Condensate tanks emissions are controlled by a 98% DRE control device, emissions have been accounted for at source (010) "Enclose Flare or Utility Flare".b - Divert tanks are used only during upset conditions (i.e., when condensate does not meet sales specifications), quantification of emissions is not required.c - Produced water tank vent lines are connected to the condensate tank vent system and go to flare, these controlled emissionsare accounted for at source (010) "EnclosedFlare or Utility Flare".d - Burner emissions based on EPA AP-42 emission factors from Section 1.4, Tables 1.4-1 and 1.4-2 for uncontrolled natural gasburners (July 1998), the worst case assumptionthat burners operate 8,760 hours per year and a fuel heating value of 1430 Btu/SCF.e - Heater Treater vent (casing head gas) VOC and HAP emissions are routed to flare if there is no pipeline availability. These controlled emissions are accounted for atsource (010) "Enclosed Flare or Utility Flare", representing a worst-case scenerio in which casing head gas goes to flareand not to pipeline.f - Generator engine emissions are estimated using 400 Hp diesel fueled tier II engine emission factors. These engines are trailer mounted and are expected to be portable.Engine emissions have been listed here to ensure that all emissions sources have been identified due to uncertainty of when utility power will be available.g - Truck loadout emissions were based on worst case assumption that produced liquids will be trucked from the facility year round, due to uncertainty of pipeline.h - Fugitive component type and count is an estimate, the emissions were calculated using EPA Table 2-4 for E&P production facilities.i - All casing head gas (from heater treater) and condensate storage tank emissions are sent to a 98% DRE Enclosed Flare or Utility Flare.Controlled Production Equipment EmissionsLesair Environmental, Inc.www.lesair.com

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.4

Emission Calculations

Prepared for: Prepared by:

QEP Energy Company Lesair Environmental, Inc.

www.Lesair.com

### Lesair Environmental, Inc.

www.lesair.com 

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Condensate Storage Tank Emissions Calculations

VOC, Benzene & n-Hexane Emissions

Annualized Production (BPY): 377,170 Control Description: Utility Flare

Production While Controls Operational: 377,170 Control Efficiency: 98%

Production forecasts are based on the first year of production for similar wells in the area. Production decline was built into the

annualized total.

VOC lb/bbl was calculated using BRE Promax software and a representative pressurized liquid analysis (Rupple).

Production while controls operational represents the portion of this facilities production where the tank emissions were

controlled.

NOx and CO emission factors were taken from Table 4 of the Texas Natural Resource Conservation Commission's (TNRCC) "Air Permit Technical Guidance for Chemical Sources - Flares and Vapor Oxidizers" document. The waste gas stream is assumed to be high-Btu (> 1,000 Btu/scf).

Facility County VOC (lb/bbl) Total HAP (lb/bbl) n-Hexane (lb/bbl) NOx (lb/MMBtu) CO (lb/MMBtu)

Dunn 11.878 0.116 0.104 0.138 0.2755

Actual Emission Calculations:

VOC (ton/yr) Total HAP (TPY) n-Hexane (TPY) Flash Gas (MMBtu/yr) 2,240.1 21.9 19.7 103,389

VOC (ton/yr) Total HAP (TPY) n-Hexane (TPY) NOx (ton/yr)

44.8 0.4 0.4 44.80 14.24 *N-hexane is the largest HAP, it is used to indicate potential for Title V applicability.

Example Calculations:

NOTE: Flash gas heat content, molecular weight and VOC fraction are estimated based on ProMax 3.0 emission simulations using composite flash gas analysis for these facilities. CO (ton/yr) Controlled Emissions Uncontrolled Emissions



###      

⋅        

=        

bbl lb Factor Emission
yr bbl Throughput ed Uncontroll Annual
yr lb Emissions ed Uncontroll



## ( )

     

⋅        

+ −⋅      

⋅        

=        

bbl lb Factor Emission
yr bbl Throughput ed Uncontroll Annual Effciency Control bbl lb Factor Emission
yr bbl Throughput Controlled Annual
yr lb Emissions Controlled 1

     

⋅        

⋅      

=        

lb t on

yr MMBtu Gas Flash MMBtu lb Factor Emission
yr ton CONOx 2000 1 & 

###      

⋅      

⋅      

⋅      

− ⋅        

⋅      

⋅         =

       

Btu MMBtu

SCF Btu Content Heat VOC mol lb GasSCF

MW Gas ton lb

yr ton VOC ed Uncontroll yr MMBtu Gas Flash

6 

### 10 1

% 1 41.379 1 000,2      

⋅        

=        

lb ton

yr lb Emissions
yr tons Emissions VOC 000,2 1

### Company Name: QEP Energy Company Facility Name: 4-35E Facility

Flash Gas Flash Gas (lb/h) (lb/bbl)

Methane 0.071 0.172

Ethane 0.732 1.756 Propane 2.233 5.359

i-Butane 0.454 1.091

n-Butane 1.447 3.472

Neo-Pentane 0.000 0.000

i-Pentane 0.268 0.644

n-Pentane 0.329 0.790 2-2-Dimethylbutane 0.001 0.001 2-3-Dimethylbutane 0.013 0.032 2-Methylpentane 0.042 0.100 3-Methylpentane 0.027 0.065

n-Hexane 0.044 0.104 n-Heptane 0.055 0.131

n-Octane 0.021 0.050

n-Nonane 0.003 0.008

n-Decane 0.008 0.018 Nitrogen 0.001 0.003

Carbon Dioxide 0.015 0.036

Benzene 0.001 0.003

Toluene 0.002 0.004 Ethylbenzene 0.001 0.002 m-Xylene 0.001 0.002

Total mass Flow 5.769 13.845

Total VOC 4.949 11.878

Total HAP 0.048 0.116

Total Methane 0.071 0.172

Total CO2 0.015 0.036

Flash Gas values based on a BRE ProMax output using representative liquid analysis from the Rupple 1-4H-150-90 using an average of 10 BOPD, or 3650 BOPY

# This section of the document has been redacted because it

contains copyrighted information. The redacted information

can be viewed from the hard copy of the docket, which is

available at the EPA Region 8 Office upon request.

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility

Well No. 1 Well No. 2 Well No. 3 Well No. 4 Well No. 5 Total Pad Production

Month # Oil (bbl) Gas (mcf) Oil (bbl) Gas (mcf) Oil (bbl) Gas (mcf) Oil (bbl) Gas (mcf) Oil (bbl) Gas (mcf) Oil (bbl) Gas (mcf)

1 13,805 8,283 13,805 8,283 13,805 8,283 13,805 8,283 13,805 8,283 69,026 41,416

2 9,505 5,703 9,505 5,703 9,505 5,703 9,505 5,703 9,505 5,703 47,525 28,515

3 7,726 4,636 7,726 4,636 7,726 4,636 7,726 4,636 7,726 4,636 38,630 23,178

4 6,681 4,008 6,681 4,008 6,681 4,008 6,681 4,008 6,681 4,008 33,403 20,042

5 5,971 3,583 5,971 3,583 5,971 3,583 5,971 3,583 5,971 3,583 29,855 17,913

6 5,449 3,269 5,449 3,269 5,449 3,269 5,449 3,269 5,449 3,269 27,243 16,346

7 5,043 3,026 5,043 3,026 5,043 3,026 5,043 3,026 5,043 3,026 25,217 15,130

8 4,717 2,830 4,717 2,830 4,717 2,830 4,717 2,830 4,717 2,830 23,584 14,151

9 4,447 2,668 4,447 2,668 4,447 2,668 4,447 2,668 4,447 2,668 22,233 13,340

10 4,218 2,531 4,218 2,531 4,218 2,531 4,218 2,531 4,218 2,531 21,091 12,655

11 4,022 2,413 4,022 2,413 4,022 2,413 4,022 2,413 4,022 2,413 20,108 12,065

12 3,850 2,310 3,850 2,310 3,850 2,310 3,850 2,310 3,850 2,310 19,251 11,551

Total 75,433 75,433 75,433 75,433 75,433 

### 377,167 226,300

BOPD 206.67 206.67 206.67 206.67 206.67 

## Estimate Annual Production**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: Company Name: QEP Energy
Facility Name: Facility: 4-35E



## Enclosed Flare Emission Analysis Worksheet

(Based on Office of Air Quality Planning and Standards, EPA, AP-42 Manual, Fifth Edition, January 1995, Section 13.5)

Source with vapors sent to the

Combustion Chamber Vapor Volume (MSCFD) Vapor Heating

Value (Btu/scf) H2S

Content

(%) Nox (lb/hr) NOx (TPY) CO (lb/hr) CO (TPY) SO2 (lb/hr) SO2 (TPY) VOC (lb/hr) VOC (TPY) HAPs (lb/hr) HAPs (TPY)

Casing head Gas 

### 620 1438 0 5.13 22.45 10.23 44.8 0.00 0.00 18.68 81.81 0.43 1.90

Condensate Tank Vapors 

### 116 2443 0 1.63 7.13 3.25 14.2 0.00 0.00 10.23 44.80 0.10 0.44

Pilot Gas 

### 0.6 1438 0 0.00 0.02 0.01 0.0 0.00 0.00 0.02 0.08 0.00 0.00

Total 737 6.76 29.61 13.50 59.11 0.00 0.00 28.92 126.69 0.54 2.34

NOTES: 1 - Condensate vapors are based on 112.2 SCF/bbl from BR&E ProMax simulation from a representative liquid analysis (Rupple). 2 - Enclosed flare or Utility Flare VOC emissions based on 98% destruction efficiency of the control equipment. 3 - NOx and CO emission factors were taken from Table 4 of the Texas Natural Resource Conservation Commission's (TNRCC) "Air Permit Technical Guidance for Chemical Sources - Flares and Vapor Oxidizers" document. The waste gas stream is assumed to be high-Btu (> 1,000 Btu/scf).

Pilot Gas (SCF/hr) (hrs/day) Pilot Gas (SCFD)

25 24 600**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: QEP Energy Company Facility Name: 4-35E Facility



## Emission Calculation for Internal Combustion Sources

Diesel Engine Emission Claulations

(For Estimating Emissions, Using Emission Factors from EPA AP-42, Table 3.3-1)



## Generator Data

Annual Fuel

I.D. Quantity Engine Equipment 1 Op Time Type

No. (Hp) (hours)

006 1 400 Portable Generator 8760 Diesel

007 1 400 Portable Generator 8760 Diesel

1 - Portable diesel (Dual Fueled, Tier II) engine driven generators are trailer mounted, they are accounted for as it is
unknown when utility power will become available.



## Emission Factors

Reference Generator

No. HP NOx CO SO 2 PM TOC 2 VOC 3 CO 2 (g/hp-hr) (g/hp-hr) (g/hp-hr) (g/hp-hr) (g/hp-hr) (g/hp-hr) (g/hp-hr)

006 400 4.800 2.600 0.931 0.150 1.000 1.000 522.100

007 400 4.800 2.600 0.931 0.150 1.000 1.000 522.100

Tier II Tier II AP-42 Tier II Tier II Tier II AP-42

2- Total Organic Compunds (TOC)
3 - VOC emission factor determined by using worst case TOC factor.
4 - SO2 and CO2 emission factors are from AP-42 Table 3.3-1, all other emission factors are based on EPA Tier II Emissions Standards.

Emissions (Lb/Hr) = E.F. (g/hp-hr)*(1lb/454g) * Horsepower

Emissions (TPY) = Emissions (Lb/Hr) * Annual Operating Time (Hr/Yr) * 1 ton/2,000 Lb

Reference

No.
(Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY)

006 4.23 18.52 2.29 10.03 0.82 3.59 0.13 0.58 0.88 3.86 460.00 2014.80

007 4.23 18.52 2.29 10.03 0.82 3.59 0.13 0.58 0.88 3.86 460.00 2014.80

TOTAL 8.46 37.05 4.58 20.07 1.64 7.18 0.26 1.16 1.76 7.72 920.00 4029.60 Emission Factors

Source Emissions

CO 2 EF Source



## Source Emissions

NOx CO SO 2 PM VOC**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Emission Calculation for External Combustion Sources

AP-42 Calculation Method

(For Estimating Emissions, Using Emission Factors from EPA AP-42, Table 1.4-1 and Table 1.4-2)



## Burner Data

Burner Annual Fuel Fuel Htg Fraction

I.D. QTY Rating Equipment Op Time Type Value of

No. (MMBtu/Hr) (hours) (Btu/scf) VOC 1

004 1 0.500 Heater Treater 8760 Field 1440 0.47

005 1 0.500 Heater Treater 8760 Field 1440 0.47

1 - Fraction of VOC is derived from the fuel gas analysis (MW VOC /MW TOTAL )



## Emission Factors

Reference Burner

No. Rating NOx CO SO 2 PM TOC 2 VOC 3 CO2

(MMBtu/Hr) (Lb/MMFt 3 ) (Lb/MMFt 3 ) (Lb/MMFt 3 ) (Lb/MMFt 3 ) (Lb/MMFt 3 ) (Lb/MMFt 3 ) (Lb/MMFt 3 )

004 0.500 100.0 84.0 0.6 7.6 11.0 5.1 120000.0

005 0.500 100.0 84.0 0.6 7.6 11.0 5.1 120000.0

AP-42 AP-42 AP-42 AP-42 AP-42 Estimate Estimate

2- Total Organic Compunds (TOC)
3 - VOC emission factor determined by taking TOC factor times fraction of fuel gas that was VOC.

Emissions (Lb/Hr) = E.F. (Lb/MMft3) * FHV/1020 * Burner Rating (MMbtu/Hr) * 1/1020 (btu/scf) * 1 MMft3/1x106 ft3 * 1x106 Btu/MMbtu

Emissions (TPY) = Emissions (Lb/Hr) * Annual Operating Time (Hr/Yr) * 1 ton/2,000 Lb

Reference

No.
(Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY) (Lb/Hr) (TPY)

004 0.07 0.30 0.06 0.25 0.00 0.00 0.01 0.02 0.00 0.02 83.04 363.74

005 0.07 0.30 0.06 0.25 0.00 0.00 0.01 0.02 0.00 0.02 83.04 363.74

TOTAL 0.14 0.61 0.12 0.51 0.00 0.00 0.01 0.05 0.01 0.03 166.09 727.47 CO2 Emission Factors

EF Source

NOx CO SO 2 PM VOC Source Emissions 

## Source Emissions**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility 

## Fugitives Emission Calculation

Equipment Service Category
Component Type Gas Heavy Oil 3 Light Oil Water/Light Oil 2

(<20 API Gravity) (>20 API Gravity)

(lbs/hr/component) (lbs/hr/component) (lbs/hr/component) (lbs/hr/component) 

### Connectors 2.00E-04 7.50E-06 2.10E-04 1.10E-04



### Flanges 3.90E-04 3.90E-07 1.10E-04 2.90E-06 

### Open-ended Lines 2.00E-03 1.40E-04 1.40E-03 2.50E-04 

### Pumps 2.40E-03 0.00E+00 1.30E-02 2.40E-05 

### Valves 4.50E-03 8.40E-06 2.50E-03 9.80E-05 

### Other 1 8.80E-03 3.20E-05 7.50E-03 1.40E-02

* - All factors are for total organic compound emission rates (includes non-VOC's such as methane and ethane).
1 - "Other" equipment type includes compressors, pressure relief valves, relief valves, diaphrams, drains,

dump arms, hatches, instruments, meters, polished rods and vents.
2 - Water/Light Oil factors apply to water streams in oil service with a water content greater than 50% to 99%
For streams with water content greater than 99%, the emission rate is considered negligable.

3 - The emission factor for pumps was not derived in the actual protocol, the factor for "other" has been
substituted for completeness.

**INPUTS:**

**1.** 

### List the quantity of each type of component in each type of service at the applicant's facility:

Equipment Service Category
Component Type Gas Heavy Oil Light Oil Water/Light Oil

(<20 API Gravity) (>20 API Gravity)


### Connectors 737 0 240 0



### Flanges 17 0 4 0 

### Open-ended Lines 12 0 4 0 

### Pumps 0 0 0 0


### Valves 74 0 50 0


### Other 0 0 0 0

NOTE: This component count is based on estimates of counts at similar facilitie



### Sample Calculation:

TOC (TPY) = component quantity * component factor * 8,760 hr/yr * 1 ton/2,000 lb.s VOC (TPY) = TOC * VOC Fraction from gas analysis (wt%)

Equipment Service Category
Component Type Gas Heavy Oil Light Oil Water/Light Oil

(<20 API Gravity) (>20 API Gravity)
(TPY of TOC) (TPY of TOC) (TPY of TOC) (TPY of TOC)



### Connectors 0.645612 0.000000 0.220752 0.000000



### Flanges 0.029039 0.000000 0.001927 0.000000 

### Open-ended Lines 0.105120 0.000000 0.024528 0.000000 

### Pumps 0.000000 0.000000 0.000000 0.000000


### Valves 1.458540 0.000000 0.547500 0.000000


### Other 0.000000 0.000000 0.000000 0.000000


### TOTAL 2.238311 0.000000 0.794707 0.000000

Weight VOC Fraction 0.4670 0.00 1.00 1.00 Weight Benzene Fraction 0.0001 0.00 0.033 0.033 Weight Toluene Fraction 0.0001 0.00 0.033 0.033 Weight Ethylbenzene Fraction 0.0000 0.00 0.033 0.033 Weight Xylenes Fraction 0.0000 0.00 0.033 0.033 Weight n-Hexane Fraction 0.0004 0.00 0.033 0.033

TPY VOC 1.05 0.00 0.79 0.00 lb/yrs VOC 2090.40 0.00 1589.41 0.00

TPY Benzene 0.00 0.00 0.03 0.00 lb/yrs Benzene 0.32 0.00 52.45 0.00

TPY Toluene 0.00 0.00 0.03 0.00 lb/yrs Toluene 0.33 0.00 52.45 0.00

TPY Ethylbenzene 0.00 0.00 0.03 0.00 lb/yrs Ethylbenzene 0.02 0.00 52.45 0.00

TPY Xylenes 0.00 0.00 0.03 0.00 lb/yrs Xylenes 0.10 0.00 52.45 0.00

TPY n-Hexane 0.00 0.00 0.03 0.00 lb/yrs n-Hexane 1.59 0.00 52.45 0.00



### (lb/yr) (TPY) (lb/yr) (TPY)
Fugitives 

### 3679.81 1.84 264.61 0.13 

## Equipment Leak Emission Estimates for Oil and Gas Production Operations

(Emission Factors Derived From Table 2-4, EPA-453/R-95-017, "Protocol for Equipment Leak emission Estimates", November 1995)

Source 

### VOC Total HAPs**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: QEP Energy Company Facility Name: 4-35E Facility

LL= 12.46 * S P M /T

LL = Loading loss (Lb/1,000 gal.), of liquid loaded



### S = Saturation factor (from AP-42 Table 5.2-1)



### P = True vapor pressure of liquid loaded (psia), (from AP-42 Figure 7.1-13a)



### M = Molecular weight of vapors (Lb/Lb-mole), (from composition of vapor phase as per Tanks 4.0.9d)



### T = Temperature of liquid loaded ( ° R = 460 + ° F) (Annual Average Temperature)



### S= 0.6 (For dedicated Hydrocarbon service, submerged loading)



### P= 7.25 True Vapor Pressure (psia) @ T=60 for a RVP=10 fluid



### M= 50 Lb/Lb-mole (Crude Oil RVP=5 Tanks 4.0.9d fluid properties)



### T= 60 ° F or 

### 520 ° R



### LL= 5.2116 Lb/1,000 gal. Loaded

-For a facility making: 377,170 bbl/yr or 

### 1033.34 bbl/day



### LL (TPY) = LL (Lb/1,000 gal) * annual production (bbl/yr) * 42 gal/bbl * 1ton/2000Lbs

Truck Loadout Emissions = 41.28 TPY of VOC

LL (lb/hr) = LL (Lb/1,000 gal) * 200 bbl tank truck * 42 gal/bbl * 1 hr loadout duration

Truck Loadout Emissions = 43.78 lb/hr of VOC

LL (lb/yr) Benzene= LL (TPY) VOC * 2000 (ton/lbs) / (13.7 (lb/bbl) / 0.024 (lb/bbl)) LL (lb/yr) n-Hexane = LL (TPY) VOC * 2000 (ton/lbs) / (13.7 (lb/bbl) / 0.21 (lb/bbl))

Truck Loadout Emissions = 144.63 lb/yr of Benzene

Truck Loadout Emissions = 1265.49 lb/yr of n-Hexane 

## PTE Volatile Organic Compound Emission Calculation for Truck LoadingLesair Environmental, Inc.

www.lesair.com 

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility


## Gas Analysis Calculation Sheet

Based on: Rupple 1-4 H-150-90

LHV HHV

BTU Content BTU Content Component Mole % Mole Frac. Lb/Lb mole MW VOC HAP Btu/scf Btu/scf*Mole Frac Btu/scf Btu/scf*Mole Frac

Helium 0.000 0.0000 4.00 0.00 0.0 0.00 0.0 0.00 Nitrogen 8.530 0.0853 28.02 2.39 0.0 0.00 0.0 0.00

Other Inerts 0.003 0.0000 30.00 0.00 0.0 0.00 0.0 0.00

Carbon Dioxide 0.090 0.0009 44.01 0.04 0.0 0.00 0.0 0.00

Methane 46.408 0.4641 16.04 7.44 909.4 422.04 1010.0 468.72

Ethane 19.230 0.1923 30.07 5.78 1618.7 311.28 1769.6 340.30 Propane 15.387 0.1539 44.09 6.78 6.78 2314.9 356.18 2516.1 387.14

Isobutane 1.805 0.0180 58.12 1.05 1.05 3000.4 54.15 3251.9 58.68

n-butane 5.115 0.0512 58.12 2.97 2.97 3010.8 154.01 3262.3 166.87 Isopentane 0.965 0.0097 72.15 0.70 0.70 3699.0 35.70 4000.9 38.61
n-pentane 1.210 0.0121 72.15 0.87 0.87 3706.9 44.86 4008.9 48.51 Cyclopentane 0.000 0.0000 70.08 0.00 0.00 3512.2 0.00 3763.4 0.00

n-Hexane 0.248 0.0025 86.18 0.21 0.21 0.21 4404.1 10.94 4750.2 11.80 Cyclohexane 0.027 0.0003 84.18 0.02 0.02 4179.9 1.11 4481.2 1.19

Other Hexanes 0.464 0.0046 86.18 0.40 0.40 4392.7 20.40 4744.5 22.03 Heptanes 0.315 0.0032 100.21 0.32 0.32 5100.3 16.08 5500.4 17.34 Methylcyclohexane 0.026 0.0003 98.19 0.03 0.03 4863.9 1.25 5215.7 1.34 2,2,4 Trimethylpentane 0.070 0.0007 114.22 0.08 0.08 0.08 5779.1 4.05 6231.5 4.37

Benzene 0.011 0.0001 78.11 0.01 0.01 0.01 3591.1 0.39 3741.5 0.40

Toluene 0.011 0.0001 92.14 0.01 0.01 0.01 4273.7 0.48 4474.5 0.51 Ethylbenzene 0.002 0.0000 106.17 0.00 0.00 0.00 4970.7 0.09 5221.7 0.10 Xylenes 0.004 0.0000 106.17 0.00 0.00 0.00 4957.4 0.19 5208.4 0.20

C8+ Heavies 0.082 0.0008 315.00 0.26 0.26 5796.3 4.75 5794.1 4.75

Totals 100.00 1.0000 29.3727 13.7158 0.3191 1437.94 1572.86

Fraction of Vapors that are VOC: 0.4670 Fraction of Vapors that are Benzene: 0.0001
Fraction of Vapors that are HAP: 0.0109 Fraction of Vapors that are Toluene: 0.0001
Gas Specific Gravity: 1.0139 Fraction of Vapors that are Ethylbenzene: 0.0000
Fraction of Vapors that are Xylenes: 0.0000
Fraction of Vapors that are n-Hexane: 0.0004

Total Non-Extended Components 0.0819 Component Factor Mole % Mole Frac. Lb/Lb mole MW HAP

Benzene 0.0331 0.0027 0.0000 78.11 0.00 0.00

Toluene 0.0285 0.0023 0.0000 92.14 0.00 0.00 Ethylbenzene 0.0014 0.0001 0.0000 106.17 0.00 0.00 Xylenes 0.0072 0.0006 0.0000 106.17 0.00 0.00

n-Hexane 0.1479 0.0121 0.0001 86.18 0.01 0.01

Total HAPs 0.01

## QUESTAR APPLIED TECHNOLOGY

1210 D. Street, Rock Springs, Wyoming 82901

(307) 352-7292

LIMS ID: N/A Description: Rupple 1-4 H-150-90 Analysis Date/Time: 8/31/2011 1:47 PM Field: Ft. Berthold Analyst Initials: PRP ML#: QEP / 8654

Instrument ID: Instrument 1 GC Method: Quesbtex

Data File: QPC89.D Date Sampled: 8/23/2011

Component Mol% Wt% LV%

Methane 46.4083 25.5070 36.1847

Ethane 19.2301 19.8106 23.7217 Propane 15.3866 23.2452 19.5149

Isobutane 1.8046 3.5935 2.7172

n-Butane 5.1151 10.1855 7.4226 Neopentane 0.0035 0.0088 0.0063 Isopentane 0.9616 2.3770 1.6201

n-Pentane 1.2101 2.9912 2.0173 2,2-Dimethylbutane 0.0031 0.0092 0.0060 2,3-Dimethylbutane 0.0687 0.2027 0.1295 2-Methylpentane 0.2398 0.7081 0.4581 3-Methylpentane 0.1528 0.4511 0.2869

n-Hexane 0.2484 0.7335 0.4701 Heptanes 0.4596 1.5071 0.8694

Octanes 0.0677 0.2628 0.1524

Nonanes 0.0185 0.0773 0.0435 Decanes plus 0.0015 0.0074 0.0043 Nitrogen 8.5304 8.1869 4.3047

Carbon Dioxide 0.0896 0.1351 0.0703 Oxygen 0.0000 0.0000 0.0000 Hydrogen Sulfide 0.0000 0.0000 0.0000

Total 100.0000 100.0000 100.0000 Global Properties Units

Gross BTU/Real CF 1586.1 BTU/SCF at 60°F and14.73 psia

Sat.Gross BTU/Real CF 1560.0 BTU/SCF at 60°F and14.73 psia Gas Compressibility (Z) 0.9933 Specific Gravity 1.0095 air=1 Avg Molecular Weight 29.189 gm/mole Propane GPM 4.216893 gal/MCF

Butane GPM 2.197498 gal/MCF

Gasoline GPM 1.246112 gal/MCF

26# Gasoline GPM 2.855964 gal/MCF

Total GPM 7.661883 gal/MCF

Base Mol% 97.801 %v/v

Sample Temperature: 68 °F Sample Pressure: 20 psig H2SLength of Stain Tube N/A ppmComponent Mol% Wt% LV%

Benzene 0.0108 0.0290 0.0139

Toluene 0.0113 0.0358 0.0175 Ethylbenzene 0.0019 0.0070 0.0034 M&P Xylene 0.0033 0.0122 0.0060 O-Xylene 0.0006 0.0022 0.0010 2,2,4-Trimethylpentane 0.0701 0.2743 0.1621 Cyclopentane 0.0000 0.0000 0.0000 Cyclohexane 0.0265 0.0763 0.0415 Methylcyclohexane 0.0257 0.0863 0.0475 Description: Rupple 1-4 H-150-90

GRI GlyCalc Information

Component Mol% Wt% LV%

Carbon Dioxide 0.0896 0.1351 0.0703 Hydrogen Sulfide 0 0.0000 0.0000 Nitrogen 8.5304 8.1869 4.3047

Methane 46.4083 25.5070 36.1847

Ethane 19.2301 19.8106 23.7217 Propane 15.3866 23.2452 19.5149

Isobutane 1.8046 3.5935 2.7172

n-Butane 5.1151 10.1855 7.4226 Isopentane 0.9651 2.3858 1.6264

n-Pentane 1.2101 2.9912 2.0173 Cyclopentane 0 0.0000 0.0000

n-Hexane 0.2484 0.7335 0.4701 Cyclohexane 0.0265 0.0763 0.0415

Other Hexanes 0.4644 1.3711 0.8805 Heptanes 0.3152 1.0054 0.5869 Methylcyclohexane 0.0257 0.0863 0.0475 2,2,4 Trimethylpentane 0.0701 0.2743 0.1621

Benzene 0.0108 0.0290 0.0139

Toluene 0.0113 0.0358 0.0175 Ethylbenzene 0.0019 0.0070 0.0034 Xylenes 0.0039 0.0144 0.0070

C8+ Heavies 0.0819 0.3261 0.1898

Subtotal 100.0000 100.0000 100.0000 Oxygen 0 0.0000 0.0000

Total 100.0000 100.0000 100.0000**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility

Methane CO2e CO2 Total CO2e

Ref No. Equipment Note lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY

001 (5) 400 bbl. Condensate Storage Tanks a 7.39 32.35 169.89 744.13 1.56 6.84 171.46 750.97

002 (5) 400 bbl. Divert Tanks b 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

003 (4) 400 bll. Produced Water Tanks c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

004 (1) 0.5 MMBtu/hr Heater Treater d 0.00 0.00 0.00 0.00 83.04 363.74 83.04 363.74

005 (1) 0.5 MMBtu/hr Heater Treater d 0.00 0.00 0.00 0.00 83.04 363.74 83.04 363.74

006 Casinghead Gas e 92813.47 406522.99 2134709.78 9350028.85 177.99 779.61 2134887.78 9350808.46

007 Fugitives 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Total 92820.86 406555.35 2134879.68 9350772.98 345.64 1513.92 2135225.32 9352286.90

NOTES: a - Condensate tanks emissions estimated using the process simulation software BR&E ProMAX and a like kind pressurized condensate analysis. b - Divert tanks are used only during upset conditions (i.e., when condensate does not meet sales specifications), quantification of emissions is not required. c - Produced water tank vent lines are connected to the condensate tank vent system and goes to flare. Produced water is not an emission source but the condensate that carries over is, QEP condensate emissions account for all of the potential emissions. d - Burner emissions based on EPA AP-42 emission factors from Section 1.4, Tables 1.4-1 and 1.4-2 for uncontrolled natural gas burners (July 1998), the worst case assumption that burners operate 8,760 hours per year and a fuel heating value of 1430 Btu/SCF. e - Casinghead gas emissions from heater treaters represent a worst-case scenerio in which gas is neither flared nor routed to pipeline, and all produced gas is vented to the atmosphere. 

## EPA Region 8 Minor Source Permitting Program

Potential GHG Emissions for Uncontrolled Emissions**Lesair Environmental, Inc.**

www.lesair.com 

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility


## EPA Region 8 Minor Source Permitting Program

Methane CO2e CO2 Total CO2e

Ref No. Equipment Note lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY

001 (5) 400 bbl. Condensate Storage Tanks a 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

002 (5) 400 bbl. Divert Tanks b 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

003 (4) 400 bll. Produced Water Tanks c 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

004 (1) 0.5 MMBtu/hr Heater Treater d 0.00 0.00 0.00 0.00 83.04 363.74 83.04 363.74

005 (1) 0.5 MMBtu/hr Heater Treater d 0.00 0.00 0.00 0.00 83.04 363.74 83.04 363.74

006 Casinghead Gas 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

007 Fugitives 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

008 Enclosed Flare or Utility Flare e 92813.47 406523.00 2134709.80 9350028.91 180.95 792.56 2134890.75 9350821.47

Total 92813.47 406523.00 2134709.80 9350028.91 347.04 1520.03 2135056.84 9351548.94

NOTES: a - Condensate tanks emissions estimated using the process simulation software BR&E ProMAX and a like kind pressurized condensate analysis. b - Divert tanks are used only during upset conditions (i.e., when condensate does not meet sales specifications), quantification of emissions is not required. c - Produced water tank vent lines are connected to the condensate tank vent system and goes to flare. Produced water is not an emission source but the condensate that carries over is, QEP condensate emissions account for all of the potential emissions. d - Burner emissions based on EPA AP-42 emission factors from Section 1.4, Tables 1.4-1 and 1.4-2 for uncontrolled natural gas burners (July 1998), the worst case assumption that burners operate 8,760 hours per year and a fuel heating value of 1430 Btu/SCF. e- Emission factors for Methane and CO2 calculations were taken from Table 12.2 API Compendium of Greenhouse Gas Emissions Estimation Methodologies for the Oil and Gas Industry.

Section 4-Combustion Emission Estimation Methods, 2004. 

## Potential GHG Emissions for Controlled Emissions

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.5

Other Requested Data

1. Field natural gas is used as fuel for the burners associated with the vertical heater treaters. The quanitity of natural gas used varies due to fuel consumption being regulated by a thermostat.

2. This facility typically operates 24 hours per day, 7 days a week, 52 weeks a year.

3. The only emission control anticipated for use at this facility is an enclosed flare or utility flare.

4. Air dispersion modeling is not being supplied with this application. This facility is located in an attainment area, in an undeveloped area of the Fort Berthold Reservation. The potential impacts from this facility should not require air dispersion modeling.

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment D.6

Evaluation of ESA and NHPA

### ATTACMENT D.6



## Endangered Species Act /NHPA Information for Permit Application 4

- 35E

Permission was acquired to survey the site from the allottees and BIA and the required NEPA /EA

Process commenced. E nvironmental o n

- site s were performed (BIA, Survey, Bio, Arch, THPO, &
Company Rep. ) AVOID, MOVE, and MITIGATE . The T hird P arty consultant (TP) submit ted the

Solicitation of View (SOV) letter to all affected A gencies

. The 30

- day SOV comment period is complete.

After the end of the 30

- day comment period, the TP submi t t ed a draft EA to the BIA, taking into account comments received during the SOV period. The BIA Regional Office review ed the Draft EA

and SOV comment letters, and recommend any required revisions of the EA to the TP

. A F O NSI has

been signed by BIA and the 30

- day public scoping period for the FONSI has begun and will be completed by January 31, 2012.

If no unresolved issues are raised during the 30

- day public scoping period, and if all the allottee signatures are in pl ace, BIA will approve and transmit the FONSI to the permittee.

No permits from BIA and/or BLM will be issued and no disturbance or development of the 4

- 35E can commence until all steps in the above process are completed, a FONSI is issued, and all relate d approvals are obtained from BLM/BIA.

/S6

### Company Name: QEP Energy Company
Facility Name: 4-35E Facility



## Attachment E

Emission Summary

### E . TABLE OF ESTIMATED EMISSIONS

The following table s provide the total emissions in tons/year for all pollutants from the ca lculations required in Section D of this form

, as appropriate for the use specified at the top of the form

.

E (i)

– Proposed New Facility

Pollutant Potential Emissions (tpy) Proposed Allowable

Emissions (tpy)

PM

- Particulate Matter

PM 10 - Particulate Matter less

than 10 microns in size

PM 2.5 - Particulate Matter less

than 2.5 microns in size

SOx

- Sulfur Oxides

NOx

- Nitrogen Oxides

CO

- Carbon Monoxide

VOC

- Volatile Organic Compound

Pb

- Lead and lead compounds

Fluorides

- Gaseous and particulates

H 2 SO 4 - Sulfuric Acid Mist

H 2 S

- Hydrogen Sulfide

TRS

- Total Reduced Sulfur

RSC

- Reduced Sulfur Compounds PM 

## 1.20 1.20

PM 10 

## 1.20 1.20

PM 2.5 

## 1.20 1.20

SO

x 

## 7.19 7.19

NO

x 

## 37.65 67.26

CO 

## 20.58 79.69

VOC 

## 6381.39 177.56

Pb 

## 0.0 0.0

Fluorides 

## 0.0 0.0

H 2 SO 4 

## 0.0 0.0

H 2 S 

## 0.0 0.0

TRS 

## 0.0 0.0

RSC 

## 0.0 0.0

E missions calculations must include fugitive emissions if the source is one the following listed sources, pursuant to CAA Section 302(j):

(a) Coal cleaning plants (with thermal dryers); (b) Kraft pulp mills; (c) Portland cement plants; (d) Primary zinc smelters; (e) Iron and steel mills; (f) Primary aluminu m ore reduction plants; (g) Primary copper smelters; (h) Municipal incinerators capable of charging more than 250 tons of refuse per day; (i) Hydrofluoric, sulfuric, or nitric acid plants; (j) Petroleum refineries; (k) Lime plants; (l) Phosphate rock processing plants; (m) Coke oven batteries; (n) Sulfur recovery plants; (o) Carbon black plants (furnace process); (p) Primary lead smelters; (q) Fuel conversion plants; (r) Sintering plants; (s) Secondary metal production plants; (t) Chemical process plants (u) Fossil

- fuel boilers (or combination thereof) totaling more than 250 million British thermal units per hour heat input; (v) Petroleum storage and transfer units with a total storage capacity exceeding 300,000 barrels; (w) Taconite ore processing plants; (x) Glass fiber processing plants; (y) Charcoal production plants; (z) Fossil fuel

- fired steam electric plants of more that 250 million British thermal units per hour heat input,

and (aa) Any other stationary source category which, as of August 7, 1980, is being regulated under section 111 or

112 of the Act.

### E (ii)

– Proposed New Construction at an Existing Facility or Modification of an Existing Facility

Pollutant Current

Actual

Emissions (tpy) Current

Allowable

Emissions (tpy) Post

- Change

Potential

Emissions (tpy) Post

- Change

Allowable

Emissions (tpy)

PM

PM 10

PM 2.5

SO

x

NO

x

CO

VOC

Pb

NH 3

Fluorides

H 2 SO 4

H 2 S

TRS

RSC

PM

- Particulate Matter

PM 10 - Particulate Matter less than 10 microns in size

PM 2.5 - Particulate Matter less than 2.5 microns in size

SOx

- Sulfur Oxides

NOx

- Nitrogen Oxides

CO

- Carbon Monoxide

VOC

- Volatile Organic Co mpound

Pb

- Lead and lead compounds

NH 3 - Ammonia

Fluorides

- Gaseous and particulates

H 2 SO 4 - Sulfuric Acid Mist

H 2 S

- Hydrogen Sulfide

TRS

- Total Reduced Sulfur

RSC

- Reduced Sulfur Compounds

# End of Facility 4-35E Application