OMB Control No. 2060-0328 Expires 07/31/2011



# Annual Report

2010

Production

Sector Company Information

Company Name:

Contact:

Title:

Address:

City, State, Zip Code:

Telephone:

Fax:

E-mail:



## Annual Report Summary

BMP 1: Identify and replace high-bleed pneumatic devices

BMP 2: Install flash tank separators on glycol dehydrators

Partner Reported Opportunities (please specify):

Period covered by report: From: To:

Partner Signature Required:

I hereby certify the accuracy of the data contained in this report.

____________________________________________________________
Date



###  Because the implementation of some technolog ies reduces emissions for multiple years, Natural Gas STAR allows certain activitie s to count towards a company’s emission reductions beyond the initial year of implementation. Natural Gas STAR designates the maximum leng th of time that these reductions may accrue as “sunset dates.” The Appendi x lists these sunset dates. Companies can report the correspondi ng methane emission reductions each year up to the allowable sunset date. Or , companies may wish to report reductions only once for the im plementation year, and have EPA automatically apply the sunset date and count those emissions for the allowable number of years.



###  In addition to reporting methane emissions reductions, you are welcome to include ot her information about your company’s partic ipation in Natural Gas STAR in the “Additional Program Accomplishments” section of this form. The Natural Gas STAR Program will use any in formation entered in this section to recognize the effo rts and accomplishments of outstanding partners.

EPA Form No. 5900-104

## Production Sector Annual Report

OMB Control No. 2060-0328 Expires 07/31/2011



## BMP 1: Identify and Replace High-Bleed Pneumatic Devices

Current Year Activities

A. Facility/location identifier information:

B. Facility summary: Number of devices replaced:

Percent of system now equipped with

low/no-bleed units: devices

% C. Cost summary:

Estimated cost per replacement (including equipment and labor): $ /replacement

D. Methane emissions reduction: Mcf E. Are these emissions reductions a one-year reduction or a multi-year reduction? One-year Multi-year

If Multi-year: Partner will report this activity once and let EPA automatically calculate future emission reductions based on sunset date duration (BMP 1 has a sunset period of 7 years).

Partner will report this ac tivity annually up to allowed

sunset date.

Please identify the basis for the emissions reduction estimat e, using the space provided to show any calculations

Standard calculation

Methane emissions reduction = [A nnual emissions from high-bleed devices being replaced (in Mcf/yr) - Annual emissions for the replacement devices (i n Mcf/yr)] x Number of devices replaced

Please specify your data source:



# o Field measurement



# o Manufacturer specifications Calculation using default

Methane emissions reduction = 124 Mcf/y r x Number of devices replaced

Other ( please specify):

F. Total value of gas saved: $

Total value of gas saved = Methane emissions reduction (in Mcf) x Gas value (in $/Mcf) [If not known, use default of $7.00/Mcf] G. How many high-bleed devices do you plan to replace next year? devices



## Previous Years' Activities

Use the table below to report any past activi ties implemented, but not previously reported to the Natural Gas STAR Program

Year # Devices Replaced Total Cost of Replacements (incl. equipment and labor) ($) Estimated Reductions (Mcf/yr) Value of Gas Saved ($)

BMP 1 Comments: Please use the back of the page for additional space if needed.

## Production Sector Annual Report

OMB Control No. 2060-0328 Expires 07/31/2011



## BMP 2: Install Flash Tank Separ ators on Glycol Dehydrators

Current Year Activities

A. Facility/location identifier information:

B. Facility summary: Number of flash tank separators

installed:

Percent of dehydrators in system equipped with flash tank separators: separators

% C. Cost summary: Estimated cost per flash tank separator installation (including equipment and labor): $ /installation

D. Methane emissions reduction: Mcf E. Are these emissions reductions a one-year reduction or a multi-year reduction? One-year Multi-year

If Multi-year: Partner will report this activity once and let EPA automatically calculate future emission reductions based on sunset date duration (BMP 2 has a sunset period of 10 years).

Partner will report this ac tivity annually up to allowed

sunset date.

Please identify the basis for the emissions reduction estimat e, using the space provided to show any calculations

Standard calculation

Methane emissions reduction per fl ash tank installation = [TEG circulation rate (in gal/hr) x Metha ne entrainment rate (in scf/gal)* x hours of operation (in hrs/yr) x 0.90] / 1,000

Please specify your data source:



# o Field measurement



# o Manufacturer specifications Calculation using default

Methane emissions reduction = [Aver age gas throughput (in MMcf/yr) x 170 scf/MMcf x 0.90] / 1,000

Other ( please specify) :

F. Total value of gas saved: $

Total value of gas saved= Methane emissions reduction (in Mcf) x Gas value (in $/Mcf) [If not known, use default of $7.00/Mcf] G. How many flash tank separators do you plan to install next year? flash tank
separators



## Previous Years' Activities

Use the table below to report any past activi ties implemented, but not previously reported to the Natural Gas STAR Program

Year # Flash Tank Separators Installed Total Cost of Installation (incl. equipment and labor) ($) Estimated Reductions (Mcf/yr) Value of Gas Saved ($)

BMP 2 Comments: Please use the back of the page for additional space if needed. *If methane entrainment rate is not known, use a default value of 3 scf/gal for energy exchange pumps or 1 scf/gal for electric pumps

## Production Sector Annual Report

OMB Control No. 2060-0328 Expires 07/31/2011 

## Partner Reported Opportunities (PROs)

For more details on PROs, visit epa.gov/gasstar/tools/recommended.html



## Current Year Activities

A. Facility/location identifier information:

B. Activity description: Please provide a separate PRO reporting form for each activity reported. If reporting a DI&M activity, please use a separate page for each location/facility surveyed.

Please specify the technology or practice that was implemented (choose from the list in the appendix or describe your own): Please describe how your company implemented this activity:

C. Level of Implementation (check one) : D. Are emissions reductions a one-year reduction or a multi-year reduction? One-year Multi-year

If Multi-year: Partner will report this activity once and let EPA automatically calculate future emission reductions based

on sunset date duration*.

Partner will report this acti vity annually up to allowed

sunset date. Number of units installed: Frequency of practice: units times/year

E. Methane emissions reduction: Mcf F. Cost summary: Estimated cost of implementing this practice/activity (including equipment and labor) : $

Please identify the basis for the emissions reduction estimat e, using the space provided to show any calculations

Actual field measurement Other ( please specify):

Calculation using manufacturer specifications/other source

G. Total value of gas saved: $

Total value of gas saved = Methane emissions reduction (in Mcf) x Gas value (in $/Mcf) [If not known, use default of $7.00/Mcf] H. To what extent do you expect to implement this practice next year?



## Previous Years' Activities

Use the table below to report any past implementat ion of this PRO, but not previously reported to Natural Gas STAR

Year Frequency of Practice/Activity or #

of Installations Total Cost of Practice/Activity (incl. equipment and labor) ($) Estimated Reductions (Mcf/yr) Value of Gas Saved ($)

PRO Comments: Please use the back of the page for additional space if needed.

* Because the implementation of some technologi es reduces emissions for multiple years, Natural Gas STAR allows certain activitie s to count towards a company’s emission reductions beyond the initial year of implement ation. Natural Gas STAR designates the maximum length of time that these reductions may accrue as “sunset dates.” The Appendix lists these sunset dates. Companies can repo rt the corresponding methane emission reduct ions each year up to the allowable sunset date. Or, companies may wish to report reduc tions only once for the implement ation year, and have EPA automati cally apply the sunset date

and count those emissions for th e allowable number of years.

## Production Sector Annual Report

OMB Control No. 2060-0328 Expires 07/31/2011



## Additional Program Accomplishments

The Natural Gas STAR Program will use any information ente red here to recognize the efforts and achievements of outstanding partners.

Please include any additional information you would like to share about your company’s participation in Natural Gas STAR. Examples may include:

 Activities to strengthen your program (e.g., training/e ducation, innovative technologies or activities, pilot projects, employee incentive programs).

 Efforts to communicate your participation and success es (e.g., internal newsletters, press releases, company website).

 Participation in Natural Gas STAR program activiti es (e.g., contributions to case studies, presentation at annual workshop).

Additional Accomplishments:

Additional Accomplishments Comments : Please use the back of the page for additional space if needed.

## Production Sector Annual Report

OMB Control No. 2060-0328 Expires 07/31/2011 

## Appendix

Methane Emission Reduction Technologies & Practices—

Production Sector

The list below describes a variety of methane emission reduction technologies that Natural Gas STAR partners in the production sector have implemented and reported to Natural Gas STAR. You may use this list as a guide when completing your annual report. Sunset dates (i.e., the length of time a technology or practice can continue to accrue emission reductions after implemented) are one year in durati on unless otherwise noted in parentheses. An asterisk (*) indicates that a technical document related to the technology or practice is available online at epa.gov/gasstar/tools/recommended.html. Compressors/Engines



###  Automate compressor syst ems operation to reduce venting*



###  Catalytic converter installation (10 years)



###  Convert engine starting to nitrogen and/or CO 2 rich gas (10 years)*



###  Convert to low pressure compre ssor starters (10 years)



###  Eliminate unnecessary equipment and/or systems*



###  Increase compression capacity to reduce venting/flaring



###  Install automated air/fuel ratio control systems (10 years)*



###  Install electric comp ressors (10 years)*



###  Install electric motors (10 years)



###  Install electric starters (10 years)*



###  Install lean burn compressor (10 years)



###  Lower compressor purge pressure for shutdown*



###  Perform gas recovery usin g slipstream (10 years)



###  Redesign blowdown/alter ESD practices*



###  Reduce emissions when taking compressors offline*



###  Replace compressor rod packing systems*



###  Replace gas starters with air (10 years)*



###  Replace ignition/reduce false starts*



###  Turbine fuel use optimization

Dehydrators



###  Install condensers on glyco l dehydrators (10 years)



###  Install/convert gas-driven c hemical pumps to electric, mechanical, or solar pumps (10 years)*



###  Install desiccant dehydrator (10 years)*



###  Reduce glycol circulation rates in dehydrators*



###  Reroute dehy./tank vents to flare or station suction (10 years)*



###  Reroute glycol skimmer gas*



###  Shutdown glycol dehydrator stripping gas in winter



###  Use rich glycol in glycol pumps

Directed Inspection and Maintenance



###  DI&M at compressor stations*



###  DI&M: leak detection using IR camera/optical imaging



###  DI&M: leak detection using lower emission threshold



###  DI&M: survey and repair leaks Pipelines



###  Inject blowdown gas into low pr essure system*



###  Pipeline replacement and repair



###  Use fixed/portable comp ressors for pipeline pumpdown*



###  Use hot taps for in-service pipeline connections*

Pneumatics/Controls



###  Capture/use gas released from gas-operated pneumatic pumps



###  Convert gas-driven chemical pumps to instrument air (10 years)*



###  Convert gas pneumatic controls to instrument air (10 years)*



###  Convert pneumatic devices to mechanical/electronic (10 years)*



###  Install/convert gas powered separators to solar separators (10 years)



###  Install controllers on gas-assisted methanol pump (10 years)



###  Install no bleed controllers (10 years)



###  Install non-venting dump controllers (10 years)



###  Reduce gas pressure on pneumatic devices



###  Reduce venting from unlit pilot: install electronic safety devices (10 years)*



###  Replace bi-directional orifice meter with ultrasonic

meters*



###  Replace chemical pumps with electronic flow controllers (10 years)



###  Use add-on controls to reduce emissions from pneumatics (10 years)

Tanks



###  Change out vent pallet (10 years)



###  Consolidate crude oil production and water storage tanks (10 years)*



###  Convert water tank blanket from natural gas to CO 2 (10 years)*



###  Install evactors (10 years)



###  Install flash gas compressors (10 years)



###  Install hydrocarbon liqui d stabilizer (10 years)



###  Install pressurized storage of condensate (10 years)*



###  Install vapor recovery uni ts (VRUs) (10 years)*



###  Install vapor recovery units on pipeline liquid/condensate tanks (10 years)*OMB Control No. 2060-0328 Expires 07/31/2011



## Appendix (continued)

Tanks



###  Recycle line recover gas during condensate loading*



###  Reduce excess blanket gas blow-by to the atmosphere



###  Replace leaking abovegr ound tanks (10 years)



###  Route gas to compressor suction/blowcase vessel (10 years)



###  Use protective tank coat ings to reduce leaks (10 years)

Valves



###  Heat tracing to prevent co ntrol valves from freezing

open



###  Install plugs on valves and open ended lines (10 years)



###  Reduce venting from unlit pilot: install BASO valves (10 years)*



###  Test and repair pressure safety valves*

Wells



###  Artificial lift: gas lift (10 years)



###  Artificial lift: install plunger lifts (10 years)*



###  Artificial lift: install pumpjacks or rod pumps on gas wells (10 years)*



###  Artificial lift: install smart lift automated systems on gas wells (10 years)*



###  Artificial lift: install veloci ty tubing strings (10 years)*



###  Artificial lift: pressure swabbing



###  Artificial lift: use capilla ry strings (10 years)



###  Artificial lift: use compression (10 years)



###  Artificial lift: use pumping unit (10 years)



###  Artificial lift: use to reduce blowdown in gas wells (10 years)* 

###  Install automated shut-in cycle units to reduce well venting (10 years)



###  Install flash tank separator on water gathering system (10 years)



###  Install pumps for separators (10 years)



###  Install snubbing unit at wellhead



###  Install soap launcher/soap unit (10 years)



###  Lower heater-treater temperature*



###  Optimize gas well unloading times*



###  Perform reduced emissions completions*



###  Route casinghead gas to VRU or compressor (10 years)*



###  Use foaming agents to reduce blowdown frequency*

Other



###  Capture and use waste heat to reduce gas usage

and emissions



###  Convert natural gas fired generator to solar power (10 years)



###  Flare reduction program



###  Improve system design/operation



###  Install flares (10 years)*



###  Install purge reducer on flare (10 years)



###  Install pilotless burner controls (10 years)



###  Optimize nitrogen rejection unit to reduce methane in

N 2 reject stream*



###  Recover gas from separators



###  Re-inject gas for enhanced oil recovery



###  Re-inject gas into crude



###  Replace aged heaters with new efficient gas fired heaters (10 years)



### Mailing Information:

Standard Mail: The Natural Gas STAR Program U.S. EPA (6207J) 1200 Pennsylvania Ave, NW Washington, DC 20460

U.S.A.

Express/Overnight Mail: The Natural Gas STAR Program U.S. EPA (6207J) 1310 L Street, NW Washington, DC 20005

U.S.A. The public reporting and recordkeeping burd en for this collection of information is estimated to average 60 hours for each ne w response and 27 hours for subsequent responses. Send comments on the Agency's need for this information, the accuracy of the provided burden estimates, and any suggested methods for minimizing respondent burden, including through the use of automated collection techniques to the Director, Collection Strategies Division, U.S. Environmental Protection Agency (2822T), 1200 Pennsylvania Ave., NW, Wash ington, D.C. 20460. Include the OMB control number in any correspondence. Do not send the completed form to this

address.