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U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Revised Pursuant to 10 CFR Part 300
Guidelines for Voluntary Greenhouse Gas Reporting
U.S. Energy Information Administration
U.S. Department of Energy
July 29, 2010
20100729
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Table of Contents
Introduction..................................................................................................................................... 1
What Is the Purpose of Form EIA-1605? ............................................................................... 1
Why Report? ........................................................................................................................... 1
How Will Your Report Be Used? ........................................................................................... 1
What Are Greenhouse Gases? ................................................................................................ 1
What Are Emissions, Reductions, and Sequestration? ........................................................... 2
How Are the Instructions Organized?..................................................................................... 2
General Instructions ........................................................................................................................ 3
What Are the Reporting Deadlines? ....................................................................................... 3
Who Can Report?.................................................................................................................... 3
How Should Your Entity Be Defined? ................................................................................... 3
How Should Your Entity Be Named?..................................................................................... 3
What Can You Report?........................................................................................................... 4
What Are Registered Reductions? .......................................................................................... 4
Can You Report But Not Register Reductions? ..................................................................... 4
Can You Both Register and Report but Not Register Emission Reductions?......................... 4
What Is the Base Period? ........................................................................................................ 5
What Is the Start Year? ........................................................................................................... 5
How Must You Estimate Emission Reductions? .................................................................... 6
Should Emissions and Reductions Be Calculated at the Entity Level? .................................. 6
What Are Subentities? ............................................................................................................ 6
What Emission Sources Should You Include in the Emissions Inventory for Each
Subentity? ............................................................................................................................... 7
What Gases Can You Report? ................................................................................................ 7
Can You Report Foreign Activities?....................................................................................... 7
Are There Minimum Reporting Requirements? ..................................................................... 9
Are There Additional Requirements for Registering Reductions? ......................................... 9
How Do You Determine if You Are a Small Emitter?......................................................... 11
How Is Form EIA-1605 Organized?..................................................................................... 11
Do You Need To Complete All of Form EIA-1605? ........................................................... 12
Who Must Certify Your Report? .......................................................................................... 13
Must an Independent Third Party Verify Your Report? ....................................................... 13
What Data Protections Apply To Your Information?........................................................... 13
Do You Have Questions or Comments?............................................................................... 20
Do You Have Any Suggestions? .......................................................................................... 20
Specific Instructions for Completing Form EIA-1605 ................................................................. 21
Instructions for Schedule I, Entity Information ........................................................................ 21
Section 1. Entity Statement................................................................................................... 21
Section 2. Entity Emissions Inventory.................................................................................. 24
Section 3. Emissions Offsets................................................................................................. 48
Section 4. Entity-Level Emission Reductions ...................................................................... 49
Instructions for Schedule II, Subentity Information ................................................................. 50
Section 1. Subentity Statement ............................................................................................. 50
Section 2. Subentity Emissions Inventory ............................................................................ 52
July 29, 2010
Voluntary Reporting of Greenhouse Gases
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Section 3. Subentity Emission Reductions ........................................................................... 52
Instructions for Schedule III, Emission Reductions ................................................................. 53
Section 1. Registered Emission Reductions.......................................................................... 53
Section 2. Reported but Not Registered Emission Reductions............................................. 55
Instructions for Schedule IV, Verification and Certification.................................................... 59
Section 1. Independent Verification ..................................................................................... 59
Section 2. Reporter Self Certification................................................................................... 60
Instructions for Addendum A, Inventory of Foreign, Subentity, or Offset Emissions............. 61
Part A. Aggregated Emissions by Gas (for Independently Verified Reports Only)............. 61
Part B. Inventory of Emissions and Carbon Flux ................................................................. 61
Part C. Total Foreign, Subentity, or Offset Emissions and Carbon Flux.............................. 61
Instructions for Addendum B, Emission Reduction Methods .................................................. 62
B1. Changes in Emissions Intensity...................................................................................... 62
B2. Changes in Absolute Emissions ..................................................................................... 65
B3. Changes in Carbon Storage ............................................................................................ 67
B4. Changes in Avoided Emissions...................................................................................... 68
B5. Energy Generation and Distribution .............................................................................. 71
B6. Coal Mine Methane Recovery........................................................................................ 74
B7. Landfill Methane Recovery............................................................................................ 80
B8. Geologic Sequestration .................................................................................................. 86
B9. Electricity Transmission and Distribution Improvements ............................................. 88
B10. Capture of Methane From Anaerobic Digestion at Wastewater Treatment Facilities . 92
B11. Anaerobic Digestion of Animal Waste ........................................................................ 98
B12. Recycling of Fly Ash.................................................................................................. 100
B13. Demand-Side Management and Other Emission Reduction Programs ..................... 102
B14. Combined Heat and Power......................................................................................... 105
B15. Other Action-Specific Methods ................................................................................. 110
B16. Destruction of Chlorofluorocarbons........................................................................... 112
Instructions for Addendum C, Country-Specific Factors Used To Estimate Emissions From
Foreign Sources ...................................................................................................................... 114
Instructions for Addendum D, Non-Reporter Offset Entity Information ............................... 115
Section 1. Offset Entity Statement...................................................................................... 115
Section 2. Offset Entity Emissions Inventory..................................................................... 117
Section 3. Offset Entity-Level Reduction Methods and Reductions .................................. 117
Appendix A. North American Industrial Classification System (NAICS) Codes ...................... 118
Appendix B. U.S. Census Divisions and Abbreviations for States and U.S. Territories............ 120
Appendix C. Country Codes ....................................................................................................... 122
Appendix D. Greenhouse Gas Reduction Initiatives .................................................................. 126
Appendix E. Greenhouse Gases and Global Warming Potentials (GWP).................................. 127
Appendix F. Electricity Emission Factors .................................................................................. 128
Appendix G. Estimation Methods and Ratings........................................................................... 136
Appendix H. Fuel Emission Factors ........................................................................................... 155
Appendix I. System and Fuel Codes for Purchased Steam and Chilled/Hot Water ................... 160
Appendix J. Emission Source Codes .......................................................................................... 161
Appendix K. GDP Price Deflators.............................................................................................. 163
Appendix L. Possible Output Measures...................................................................................... 164
July 29, 2010
Voluntary Reporting of Greenhouse Gases
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Appendix M. Action Type Codes ............................................................................................... 167
Appendix N. Emission Factors for Steam and Chilled/Hot Water ............................................. 170
Glossary of Selected Terms ........................................................................................................ 174
July 29, 2010
Voluntary Reporting of Greenhouse Gases
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Introduction
What Is the Purpose of Form EIA-1605?
Form EIA-1605 collects information on greenhouse gas emissions, reductions, and sequestration under
Section 1605(b) of the Energy Policy Act (EPAct) of 1992 (42 USC 13385). The form implements the
guidelines for filing voluntary reports issued on April 21, 2006 by the Department of Energy’s (DOE)
Office of Policy and International Affairs (71 FR 20784), Guidelines for Voluntary Greenhouse Gas
Reporting (10 CFR Part 300). The purpose of the Voluntary Reporting Program is to encourage
corporations, government agencies, non-profit organizations, households, and other private and public
entities to submit annual reports of their greenhouse gas emissions, emission reductions, and sequestration
activities. Form EIA-1605 provides a means for voluntary reporting that is complete, reliable, and
consistent.
Why Report?
This voluntary reporting program gives participants the opportunity to create a public record of their
emissions, emission reductions, and/or sequestration achievements. In addition, the registration of
emission reductions may provide special recognition to those entities willing to meet additional
requirements. Reporting also provides a mechanism for initiating an informed public debate on
greenhouse gases and reduction efforts. Over time, it is anticipated that these reports will contribute to a
reliable record of contributions made toward reducing greenhouse gas emissions.
How Will Your Report Be Used?
All reports submitted to the U.S. Energy Information Administration (EIA) on Form EIA-1605 will be
entered into an electronic database designed to preserve data on emissions, emission reductions, and
sequestration achievements. All non-confidential information reported under this voluntary program will
be publicly available on a reporter-specific basis. Public access to these data will create a reliable record
of the contributions reporting entities have made toward reducing their greenhouse gas emissions.
If there is information included in your report that is believed to be a trade secret or commercial or
financial information that is exempt from public disclosure under the Freedom of Information Act (e.g.,
release to the public would cause substantial harm to your organization's competitive position), you may
request that the information be kept confidential by checking the box on Schedule I of Form EIA-1605 for
"This report contains confidential information." If you wish to request confidentiality, you must also
identify data elements for which confidentiality is requested and provide a justification for why such data
should be made confidential. See “What Data Protections Apply To Your Information?” on page 20
below for more details.
What Are Greenhouse Gases?
Greenhouse gases, found in trace quantities in the atmosphere, absorb infrared energy and prevent it from
leaving the atmosphere. Increasing levels of greenhouse gases in the atmosphere may contribute to an
increase in average global temperatures resulting in adverse climate changes. Although many gases found
in the atmosphere exhibit these properties, this reporting program focuses on the greenhouse gases most
affected by human activity: carbon dioxide, methane, nitrous oxide, hydrofluorocarbons (HFCs),
perfluorocarbons (PFCs), and sulfur hexafluoride. Chlorofluorocarbons (CFCs) and other greenhouse
July 29, 2010
Voluntary Reporting of Greenhouse Gases
1
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
gases with quantifiable climate forcing effects may also be reported as long as the Department of Energy
(DOE) has established a method for doing so. 1 CFCs must be reported separately and reductions
associated with such gases are not eligible for registration.
What Are Emissions, Reductions, and Sequestration?
Emissions are the direct release of greenhouse gases into the atmosphere from any anthropogenic (human
induced) source and certain indirect emissions (releases) specified in 10 CFR Part 300, Guidelines for
Voluntary Greenhouse Gas Reporting. A reduction is a decrease in greenhouse gas emissions.
Sequestration is the process by which carbon dioxide (CO2) is removed from the atmosphere, whether
through biologic or physical processes.
How Are the Instructions Organized?
This complete reporting package contains Form EIA-1605 and these instructions. The instructions are
divided into three main parts:
1.
2.
3.
General Instructions
Specific Instructions for Completing Form EIA-1605
Appendices
The reporting form is a separate document.
1
Up to this point, DOE has only established methods for CFCs.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
2
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
General Instructions
What Are the Reporting Deadlines?
To be included in the next annual report of greenhouse gas emissions, entity reports that are self-certified
must be submitted to EIA no later that July 1 for emissions occurring up to and through the previous
calendar year. Reports that have been independently verified must be submitted by September 1 for
emissions occurring up to and through the previous calendar year. Please note that the reporting deadlines
will not follow the aforementioned schedule during the first operational years of the program (calendar
years 2009 and 2010). During this time frame, the exact reporting deadlines can be obtained from the
Program’s webpage at http://www.eia.doe.gov/oiaf/1605/index.html.
Who Can Report?
You can submit a report if you are an entity that initiates, controls, or in some other way participates in a
United States based activity that results in the emission of greenhouse gases in the United States. 2 An
entity is the whole or part of any business, institution, organization or household that:
•
•
•
is recognized as an entity under any U.S. Federal, State, or local law that applies to it;
is located and operates, at least in part, in the United States; and
the emissions of such operations are released, at least in part, in the United States.
How Should Your Entity Be Defined?
Although DOE/EIA strongly encourages entities to define themselves at the highest level of aggregation,
reporting at some lower level is permitted. However, once an entity has determined the level of corporate
or institutional management at which it will report (e.g., the holding company, subsidiary, regulated
stationary source, state government, agency, etc.), the entity must include all elements of the organization
encompassed by that management level and exclude any organizations that are managed separately. For
example, if two subsidiaries of a parent company are covered by a single report, then all subsidiaries of
that parent company must also be included.
How Should Your Entity Be Named?
The name assigned to your entity should correspond closely to the scope of the operations and emissions
covered by its report. For entities that intend to register reductions, the name reported on Form EIA-1605
should be the name commonly used to represent the operations being reported, as long as it is not also
used to refer to a substantial operating unit not covered by the entity’s reports. If an individual plant or
operating unit of a corporation or subsidiary is reporting as an entity, it should be given a name that
corresponds to the specific plant or unit, and not to the responsible corporate or subsidiary entity. (See the
§300.3(c) of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting.)
For example, for an entity called ACME Corporation that has a subsidiary called ACME Novelty
Products, Inc., follow the guidance below.
2
As noted below, emissions and reductions on non-U.S. operations can be reported separately provided an entity has
U.S. emissions and has reported data on U.S. emissions.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
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Form EIA-1605
•
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
To report on behalf of the entity as a whole, whether or not you are including the subsidiary, use
“ACME Corporation”
To report on behalf of only the subsidiary use: “ACME Novelty Products, Inc.”
What Can You Report?
You can report a comprehensive or partial inventory of your entity’s emissions and carbon stocks, as well
as reductions in emissions, as measured against a Base Period of up to four years. Form EIA-1605 gives
you the opportunity to register reductions for 2003 and subsequent years as well as the opportunity to
report but not register reductions for 1991 and subsequent years. 3
What Are Registered Reductions?
You may register reductions if you meet specific, stringent reporting requirements designed to increase
the credibility of reported emissions and emission reductions. You can register reductions in emissions
achieved beginning in 2003 and in subsequent years as measured against a base period of up to four years
(1999-2002, or later). In order to register reductions, you must comply with the requirements of §300.1(c)
and §300.7 of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting. Upon review and
acceptance of a report, EIA will notify the entity that reductions meeting the requirements have been
credited to the entity as “registered reductions,” which can be held by the entity for use in the event a
future program that recognizes such reductions is enacted into law.
Can You Report But Not Register Reductions?
To report but not register reductions, you need to meet less stringent and more general reporting
requirements. You may report but not register information on greenhouse gas emissions for the baseline
period of 1987 through 1990 or later, and you may report but not register annual reductions of
greenhouse gas emissions and increases in carbon fixation realized in 1991 and subsequent years. Please
note that for the sake of these instructions, EIA uses the term “reporting” (without the qualifier “but not
registering”) to refer to both “registering” and “reporting but not registering” reductions.
Can You Both Register and Report but Not Register Emission
Reductions?
Reporters may submit annual reports that include emission reductions for any year from 1991 onwards;
however, registered reductions may only be included in reports for 2003 onwards. For example, a reporter
may submit a Start Year report for 1990 and submit Reporting Year reports including emission reductions
that are reported but not registered for 1991 through 2002. In addition, this reporter may submit another
Start Year report for 2002 and Reporting Year reports including registered reductions for 2003 onwards.
The Reporting Year reports containing registered reductions may also include reductions that are not
eligible for registration, including: (1) reductions of emissions from other indirect sources, (2) reductions
of CFC emissions, and (3) emission reductions calculated using the change in absolute emissions method
3
Entities that have made a commitment to reduce entity-wide emissions under the Climate Leaders or Climate
VISION program may use a Start Year derived from the Base Period of the commitment, provided it is no earlier
than 2000.
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Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
for an entity or subentity for which emission reductions calculated using the change in emissions intensity
method are also being registered. For a general overview of possible reporting options for calendar year
2007, see Figure 1 below.
What Is the Base Period?
The Base Period is a period of time from one to four years in length, against which emission reductions
are estimated. This period is used to determine the average annual base emissions, emissions intensity,
and other values from which emission reductions are calculated.
What Is the Start Year?
The Start Year is the year upon which the initial entity statement is based and must be the year
immediately preceding the first year for which the entity intends to report reductions. It is the last year of
the Base Period and can be no earlier than 2002 for registered reductions. An entity registering reductions
and participating in the Climate Leaders or Climate VISION programs may use a Base Period that ends
no earlier than 2000 if it corresponds to the Base Period the entity has established under either of those
programs. For an entity that intends to report but not register reductions, the Start Year may be no earlier
than 1990. All entities are required to file a separate Form EIA-1605 report for the Start Year. The Start
Year report may only contain inventory data, not reductions.
Figure 1. Examples of Possible Reporting Options for Calendar Year 2007
Possible reports submitted
for Calendar Year 2010
Registering reductions for
Data Year 2009
Reporting but not
registering reductions for
2009
Establish base period
ending in 2008
Establish base period prior
to 2008 (but no earlier than
2002)
Establish base period
ending in 2008
Establish base period
ending prior to 2008 (but
no earlier than 1990)
Start Year report: 2008
Star Year report: e.g. 2002
Start Year report: 2008
Start Year report: e.g.
1990
First year of registered
reductions: 2009
First year of registered
reductions: e.g. 2003
First year of reductions:
2009
First year of reductions:
e.g. 1991
Reporting Year report
submitted for 2009
Reporting Year reports
submitted for 2003-2009
Reporting Year report
submitted for 2009
Reporting Year reports
submitted for 1991-2009
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
How Must You Estimate Emission Reductions?
Emission reductions must be estimated using the following methods, which are outlined in §300.8 of 10
CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting:
• changes in emissions intensity;
• changes in absolute emissions;
• changes in carbon storage;
• changes in avoided emissions; and
• action-specific emission reductions. 4
Refer to Chapter 2 of the Technical Guidelines 5 for detailed guidance on applying these methods.
Should Emissions and Reductions Be Calculated at the Entity Level?
Large emitters intending to register reductions must include all emission sources, with the exception of de
minimis sources, in their emissions inventory and base the emission reductions they register on the total
emissions for the entity. Emission reductions may be calculated using a single method applied to total
entity-wide emissions using one of the following methods:
• changes in emissions intensity;
• changes in absolute emissions;
• changes in carbon storage (provided the entity has no other emissions or these emissions are de
minimis)
• energy generation and distribution; and
• combined heat and power.
Alternately, the entity may be divided into several subentities using different emission reduction methods,
output measures, or Base Periods; however, the total emissions of the subentities combined must equal
the total emissions of the entity. The inventory in Schedule I, Section 2 for small emitters and all entities
intending to report but not register reductions may be a partial inventory, reflecting a summation of the
emissions of all the specific activities included in the report.
What Are Subentities?
For some entities, a single emission reduction estimation method will prove sufficient. However, in many
cases entities will need to use two or more reduction estimation methods because of the disparate nature
of their various emission sources. In such cases, the entity will need to define and specify the portion of
the entity (i.e., the “subentity”) to which each method will be applied. A subentity is a component of any
entity, and can be a discrete business line, facility, plant, vehicle fleet, or energy use system, which has
greenhouse gas emissions that can be distinguished from the emissions of all other components of the
same entity. The emissions for a subentity, when summed with the emissions of all the other subentities
comprising the entity, equal the entity’s total emissions. If you intend to use more than one method to
calculate emission reductions or intend to use different output measures for the “changes in emissions
intensity” method, your entity must be divided into two or more subentities. You may or may not need to
create subentities if you are reporting emissions and reductions for operations in a foreign country (in
4
In addition to the four emission reduction methods listed above there are 12 action-specific methods that can be
used.
5
Specific guidelines for specific calculation methods are found on page 251 of the Technical Guidelines.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
addition to those from your entity’s domestic operations). If you intend to estimate emissions using the
same entity-level emission reduction method and Base Period for domestic and foreign operation and you
report all of your foreign operations together (rather than by country or region) you will not need to
establish a separate subentity for foreign emissions. If, however, your foreign operations have a different
base period or employ a different emission reduction method and/or you break up your foreign emissions
by country or region, you will need to establish separate subentities for your foreign emissions. You will
also need to establish subentities for new or acquired operations that must use a different Base Period than
the remainder of your entity.
What Emission Sources Should You Include in the Emissions
Inventory for Each Subentity?
In general, a subentity’s emissions inventory should include all emissions sources associated with the
calculation of the emission reductions for that subentity. Emissions not associated with the emission
reduction calculations for the subentity should be excluded. To the extent that certain emissions
associated with a subentity are excluded, those emissions still need to be accounted for elsewhere. For
example, a reporter using Addendum B7, Landfill Gas Recovery, to reporting emission reductions based
on captured methane, would also need to create another subentity, perhaps Addendum B1, Changes in
Emissions Intensity, or Addendum B2, Changes in Absolute Emissions, to report on the emissions
associated with the landfill, as well as quantities of methane that are not captured. To a large extent the
emissions included will depend on the method you intend to use to calculate emission reductions. Table
G1 summarizes the subentity emissions inventory requirements for each emission reduction method in
Addendum B.
What Gases Can You Report?
Your report should cover only the following greenhouse gases: 6
• Carbon Dioxide (CO2)
• Methane (CH4)
• Nitrous Oxide (N2O)
• Hydrofluorocarbons (HFCs)
• Perfluorocarbons (PFCs)
• Sulfur Hexafluoride (SF6)
• Chlorofluorocarbons (CFCs) 7
Can You Report Foreign Activities?
Emissions from foreign activities and any associated emission reductions may be reported if the entity has
U.S. emissions and has included these emissions in its report. All activities outside of the United States,
its territories, and its trusts are considered foreign activities. Foreign emissions and emission reductions
must be reported separately from domestic emissions and emission reductions, by establishing one or
6
Other gases or particles have been demonstrated to have significant, quantifiable climate forcing effects when
released into the atmosphere in significant quantities. DOE has not established or approved methods for estimating
emissions of other gases or particles at this time.
7
The reporting of CFC emissions on Form EIA-1605 is optional. CFC emissions cannot be included in total
inventory emissions since reliable net global warming potentials are not available for these gases. Reductions in
CFC emissions may be reported but not registered.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
more subentities on Form EIA-1605 unless reductions are not reported or are calculated at the entity-level
using the same method for domestic and foreign sources.
Table G1. Inventory Requirements for Entities and Subentities by Reduction Method
Emission Reduction Method
Inventory Requirement
B1.
Changes in Emissions Intensity
Include all emissions associated with the selected output measure
except those that must be included with one of the action-specific
methods described below (B5 through B16).
B2.
Changes in Absolute Emissions
Include all emissions associated with the activities of the subentity
except those that must be included with one of the action-specific
methods described below (B5 through B16).
B3.
Changes in Carbon Storage
Include all information on your entity’s carbon fluxes and stocks in a
single subentity inventory.
B4.
Changes in Avoided Emissions
Include only stationary combustion emissions associated with energy
generation in the Reporting Year. If emissions associated with energy
generation occurred during the Base Period, you must use Addendum
B5 (Emission Reductions from Energy Generation and Distribution) to
estimate reductions for your entity or subentity.
B5.
Energy Generation and Distribution
At a minimum, include stationary combustion emissions associated
with the energy generation.
B6.
Coal Mine Methane Gas Recovery
Include emissions from electricity generation from captured methane,
the emissions from the flaring of captured methane, and methane
emissions from mine ventilation before capture. Note that other
emissions associated with this activity, on-site electricity generation not
from captured methane, stationary source combustion (all fuel
sources), etc. must be reported as a separate subentity.
B7.
Landfill Methane Recovery
Include emissions from electricity generation from captured methane
and emissions of methane from the decomposition of waste before
methane capture. Note that other emissions associated with this
activity, on-site electricity generation not from captured methane,
stationary source combustion (all fuel sources), etc. must be reported
as a separate subentity.
B8.
Geologic Sequestration
No emissions need be included in the inventory associated with a
geologic sequestration activity. [Note that emissions associated with
operations of a geologic reservoir do not enter into the calculation of
reductions using this method and must be included in a separate
subentity.]
B9.
Electricity Transmission and
Distribution Improvements
No emissions need be included in the inventory associated with
electricity transmission and distribution improvements. [Note that
emissions associated with operations of a transmission and distribution
system do not enter into the calculation of reductions using this method
and must be included in a separate subentity.]
B10. Capture of Methane From Anaerobic
Digestion at Wastewater Treatment
Facilities
Include emissions from electricity generation from captured methane,
nitrous oxide emissions from anaerobic digestion, and emissions of
methane from the decomposition of wastewater before methane
capture. Note that other emissions associated with this activity, on-site
electricity generation not from captured methane, stationary source
combustion (all fuel sources), etc. must be reported as a separate
subentity.
B11. Anaerobic Digestion of Animal Waste
No emissions need be included in the inventory associated with
anaerobic digestion of animal waste. [Note that emissions associated
with the anaerobic digestion of animal waste do not enter into the
calculation of reductions using this method and must be included in a
separate subentity.]
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Emission Reduction Method
Form Approved
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Inventory Requirement
B12. Recycling of Fly Ash
No emissions need be included in the inventory associated with the
recycling of fly ash. [Note that emissions associated with the recovery
of fly ash and its transportation to the entity or entities using the fly ash
as a substitute for Portland cement do not enter into the calculation of
reductions using this method and must be included in a separate
subentity.]
B13. Demand-Side Management and Other No emissions need be included in the inventory associated with the
Reduction Programs
demand side management and other reduction programs. [Note that
emissions associated with demand side management and other
reduction programs do not enter into the calculation of reductions using
this method and must be included in a separate subentity.]
B14. Combined Heat and Power
Include the stationary combustion emissions associated with producing
energy at combined heat and power facilities.
B15. Other Action-Specific Methods
Include all emissions associated with the action-specific method.
B16. Destruction of Chlorofluorocarbons
Include emissions of chlorofluorocarbons.
Are There Minimum Reporting Requirements?
The Voluntary Reporting of Greenhouse Gases Program allows considerable flexibility in defining the
activities you report. All reporters must submit an initial Start Year report including an entity statement
that fully documents the legal basis and scope of the entity, its organization boundaries, and its base
period emissions. All reporters must certify that the Start Year report and subsequent Reporting Year
reports containing information on emission reductions are accurate and complete and the emission
reductions were calculated using methods described in the revised General and Technical Guidelines. 8
Form EIA-1605 is designed to minimize reporting burden while meeting the minimum information
requirements as defined in 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting. Table
G2 summarizes the reporting requirements for large emitters intending to register reductions, small
emitters intending to register reductions, and any entity intending to report but not register reductions.
Are There Additional Requirements for Registering Reductions?
Additional requirements for registering reductions apply to large emitters, small emitters, and
aggregators.
Large Emitters
Large emitters, or entities with annual emissions exceeding 10,000 metric tons CO2 equivalent, must
provide a comprehensive entity-wide emissions inventory that meets minimum data quality standards,
resulting in a quantity-weighted average quality rating of at least 3.0. 9 They must also calculate and report
net entity-wide emission reductions that reflect any increases in emissions experienced by one or more
sources within the entity. In addition, large emitters must maintain verifiable records for a minimum of
three years for Reporting Year data and for the duration of their participation in the 1605(b) Program for
Base Period data.
8
10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting. These guidelines are available at
http://www.eia.doe.gov/oiaf/1605/gdlins.html.
9
See §300.6(b) of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting. Ratings are explained
fully in Section 1.A.4 of the Technical Guidelines. A list of estimation methods and ratings is provided in Appendix
F of these instructions.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
9
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Table G2. Summary of Principal Reporting Requirements
Type of Reporter
Requirement
Entity Statement
Define Subentities
Emissions Inventory
Minimum Data Quality
Third-Party Verification
Self-Certification
Documentation
Start Year
Emission Reductions
First Reporting Year
Emission Reductions
Large Emitter
Registering Reductions
Small Emitter
Registering Reductions
All Reports
Required
Required
Required if more than one
Required if emission
emission reduction
reductions are calculated for
estimation method is to be
two or more activities using
used
more than one distinct
estimation methods
Entity-wide inventory
Entity-wide estimate
required
required for the first year
and after any significant
increase in emissions, any
change in operations or
boundaries, or every five
years (in Schedule I, Section
1). Otherwise, inventory
required only for activities
for which reductions are
being reported
Inventory must have
Inventory must have
average rating of 3.0 or
average rating of 3.0 or
higher
higher
Optional
General certification
required* plus additional
requirements where
applicable**
Optional
General certification
required* plus additional
certifications** where
applicable. Must certify that
actions causing reductions
are not likely to result in
emissions increases
elsewhere in the entity
For Base Period data,
For Base Period data,
verifiable records must be
verifiable records must be
maintained for duration of
maintained for duration of
participation in Program.
participation in Program. For
For Reporting Year data,
Reporting Year data,
verifiable records must be
verifiable records must be
maintained for at least 3
maintained for at least 3
years
years
Start Year Report
2002 or Later***
2002 or Later***
Not reported
Not reported
(Base Period emissions
(Base Period emissions only
only are reported)
are reported)
Reporting Year Report
2003 or later
2003 or later
2003 onwards
2003 onwards
Any Entity Reporting
But Not Registering
Reductions
Required
Required if emission
reductions are calculated
for two or more activities
using more than one
distinct estimation methods
The inventory should
reflect selected elements
of their entities, selected
gases or selected sources
for which the entity reports
reductions
Inventory need not achieve
average rating of 3.0 or
higher but a rating must be
calculated
Optional
General certification
required*
Verifiable records for Base
Period and Reporting Year
data must be maintained
for at least 3 years
1990 or Later
Not reported
(Base Period emissions
only are reported)
1991 or later
1991 onwards
*All reporters must certify accuracy, completeness, compliance with guidelines, and consistency with prior year’s report.
**Additional certification requirements address (1) double counting or reporting; (2) agreements with third parties; (3) emissions
shifting; (4) avoided emissions from acquired facilities; (5) retention of records; and (6) independent verification.
***Entities that have made a commitment to reduce entity-wide emissions under the Climate Leaders or Climate VISION program
may use a Start Year derived from the Base Period of the commitment, provided it is no earlier than 2000.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
10
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Small Emitters
Small emitters or entities with annual emissions that do not exceed 10,000 metric tons CO2 equivalent
must provide an emissions inventory only for the activities for which they intend to register emission
reductions. Small emitters must meet the same minimum data quality standards for these partial
inventories and use the same methods to calculate reductions as large emitters. In addition, small emitters
must certify that the reductions they intend to register were not caused by actions likely to cause increases
in emissions elsewhere in the entity.
Aggregators
An aggregator is an entity, such as a trade association, that submits a report on behalf of multiple nonreporting entities. The aggregator must follow the requirements that would apply to the non-reporting
entities if they had themselves reported. Aggregators should follow the procedures applicable for
reporting offset reductions obtained by agreement with a non-reporter (see the Instructions for Schedule I,
Section 3, Emission Offsets).
How Do You Determine if You Are a Small Emitter?
You can develop a preliminary estimate of your entity-wide emissions based on common physical
indicators using EIA’s Simplified Emission Inventory Tool (SEIT), 10 or the methods contained in the
Technical Guidelines, to demonstrate that your annual emissions do not exceed 10,000 metric tons CO2
equivalent. The result of this estimate must be reported to EIA. Once an entity determines that it is a small
emitter, its emissions must be re-estimated and reported to EIA (1) every five years, (2) whenever the
operations or boundaries of the entity have changed significantly, and (3) after any significant increase in
emissions. A small emitter with estimated annual emissions exceeding 9,000 metric tons CO2 equivalent
must re-estimate and submit emissions annually. See §300.5(c) of 10 CFR Part 300, Guidelines for
Voluntary Greenhouse Gas Reporting for information on determining and maintaining small emitter
status.
How Is Form EIA-1605 Organized?
Form EIA-1605 consists of four schedules (see Figure 2, below), which allow you to describe your entity,
to characterize the different aspects of your emissions and emission reduction efforts, to certify and, if
desired, to independently verify the information reported. The schedules are:
I.
II.
III.
IV.
10
Entity Information
Subentity Information
Emission Reductions Summary
Verification and Certification
The SEIT tool is available at EIA’s website at http://www.eia.doe.gov/oiaf/1605/reporting_tools.html#seit.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
11
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Figure 2. Organization of Form EIA-1605
Form EIA-1605
SCHEDULE I. ENTITY
Foreign Emissions
Addendum D
Addendum
Non-Reporter Offset
Entity Information
Section 1. Entity Statement
Section 2. Entity Emissions Inventory
Part A. Aggregated Emissions by Gas (for Independently Verified
Reports Only)
Part B. Inventory of Domestic Emissions and Carbon Flux
Part C. Inventory of Foreign Emissions and Carbon Flux
Part D. Total Emissions and Carbon Flux
Part E. Emissions Inventory Rating Summary
Section 3. Emission Offsets
Part A. Offsets Obtained by Agreement with Other Reporters
Part B. Offsets Obtained by Agreement with a Non-reporter
Section 4. Entity-Level Emission Reductions (Do not complete if
reporting subentities. Proceed to Schedule II.)
SCHEDULE II. SUBENTITY
Subentity
Emissions
Section 1. Subentity Statement
Section 2. Subentity Emissions Inventory
Section 3. Subentity Emission Reductions
SCHEDULE III. EMISSION REDUCTIONS
Addendum A
Addendum
Foreign, Subentity, or
Offset Emissions
Addendum C
Country-specific
Factors Used to
Estimate Emissions
from Foreign
Countries
Section 1. Registered Emission Reductions
Part A. Domestic Net Entity-level Reductions and Carbon Storage
Part B. Foreign Net Entity-level Reductions and Carbon Storage
Section 2. Reported But Not Registered Emission Reductions
Part A. Domestic Net Entity-level Reductions and Carbon Storage
Part B. Foreign Net Entity-level Reductions and Carbon Storage
If estimating reductions for
entire entity, complete one
copy of the appropriate
method in Addendum B
If estimating
reductions for two or
more subentities,
complete one copy
of the appropriate
method in
Addendum B for
each subentity
Multiple
Addendum B
B1- B1-B16
Addendum
Emission
Reduction
Emissio
Methods
Reductio
Metho
SCHEDULE IV. VERIFICATION AND
Section 1. Independent Verification
Section 2. Reporter Self Certification
Do You Need To Complete All of Form EIA-1605?
Reporters have to complete only those portions of the reporting form applicable to the nature of their
entity and their reporting objectives. The parts of Form EIA-1605 that must be completed for your entity
or your report depend on the following report characteristics:
•
Start Year or Reporting Year report;
•
Small or a large emitter;
•
Registered reductions included;
•
Verified by an independent third party;
•
All methods used to estimate emissions rated B or higher;
•
Emissions from foreign operations included;
•
Subentities included.
Once you have determined the characteristics of your report, use one of the following decision charts to
identify which Schedules, Sections, and Parts of Form EIA-1605 you must complete. Select the decision
chart applicable to your entity based on whether your report will be a Start Year or Reporting Year
Report, whether you are a large or small emitter, and whether you intend to register emission reductions
as follows:
•
Use Table G3 if you are completing a Start Year report for a large emitter and intend to register
reductions;
July 29, 2010
Voluntary Reporting of Greenhouse Gases
12
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Use Table G4 if you are completing a Reporting Year report for a large emitter and intend to
register reductions;
•
Use Table G5 if you are completing a Start Year report for a small emitter and intend to register
reductions;
•
Use Table G6 if you are completing a Reporting Year report for a small emitter and intend to
register reductions;
•
Use Table G7 if you are completing a Start Year report for an entity that intends to report but not
register reductions; and
•
Use Table G8 if you are completing a Reporting Year report for an entity that intends to report
but not register reductions.
When you have selected the appropriate decision table, trace the responses to the questions in the Report
Characteristics columns to find the row identifying the Schedules, Sections, and Parts of Form EIA-1605
that must be completed for your entity.
Who Must Certify Your Report?
You are required to certify the accuracy of the information you report with the signature of the certifying
official of the entity. A report submitted on behalf of a household may be certified by one of its members.
All other reports must be certified by the chief executive officer, agency head (in the case of a
government agency), or the officer or employee of the entity who is responsible for reporting the entity’s
compliance with environmental regulations.
Must an Independent Third Party Verify Your Report?
Although DOE encourages reporters to have their annual reports verified by an independent third party,
this is not a requirement for reporting on Form EIA-1605. If you do choose to have your report
independently verified, you must meet the requirements outlined in §300.11 of the General Guidelines.
What Data Protections Apply To Your Information?
Information reported on Form EIA-1605 is considered public information and may be publicly released in
an identifiable form.
Filing Forms with the Federal Government and Estimated Reporting Burden
Respondents are not required to file or reply to any Federal collection of information unless it has a valid
OMB control number. Public reporting burden for this collection of information is estimated to average
60 hours per response, including the time for reviewing instructions, searching existing data sources,
gathering and maintaining the data needed, and completing and reviewing the collection of information.
Send comments regarding this burden estimate or any other aspect of this collection of information
including suggestions for reducing this burden to: U.S. Energy Information Administration, Statistics and
Methods Group, EI-70, 1000 Independence Avenue, S.W., Washington, D.C. 20585; and to the Office of
Information and Regulatory Affairs, Office of Management and Budget, Washington, D.C. 20503.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
13
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
No
Yes
Yes
No
No
Yes
Yes
No
No
Yes
No
No
Emissions Inventory
by Source – Domestic
Emissions Inventory
by Source – Foreign
(Addendum A)
Total Emissions and
Carbon Flux
Rating Summary
Emissions Offsets
Entity-Level Emission
Reductions
✔
✔*
✔
No
✔
✔*
✔
Yes
✔
✔*
✔
No
✔
✔*
✔
Yes
✔
✔*
✔
✔
No
✔
✔*
✔
✔
Yes
✔
✔*
✔
✔
No
✔
✔*
✔
✔
Yes
✔
✔
✔
✔
No
✔
✔
✔
✔
Yes
✔
✔
✔
No
✔
Sec. 2 & Add. A
Part
Part
Part
A
B
C
✔
✔**
✔
✔
✔
Sec.
3
Sec.
1
Sec.
2
Sec.
1
Self Certification
Aggregated Emissions
by Gas (Domestic and
Foreign) †
Yes
Sec.
1
Independent
Verification
Sec.
4
Reported But not
Registered Reductions
Sec.
3
Schedule
IV
Registered Reductions
Part
E
Schedule
III
Subentity Reductions
Part
D
Total Emissions and
Carbon Flux for
Subentities
Sec. 2
Part
C
Emissions Inventory
by Source for
Subentities (Add. A)
Part
B
Aggregated Emissions
by Gas for Subentities
(Add. A)
Yes
Part
A
Subentity Statement
Yes
Entity-Wide
Reductions Only?
Foreign Emissions?
All A- or B-Rated
Methods?
Independent
Verification?
Report Characteristics
Sec.
1
Entity Statement
Table G3. Decision Chart for a Start Year Report for a Large Emitter Intending To Register Reductions
Reporting Requirements
Schedule II
Schedule I
(For Each Subentity)
✔
✔
✔
✔**
✔
✔**
✔
✔**
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
Yes
✔
✔
✔
✔
✔
No
✔
✔
✔
✔
✔
Yes
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
No
✔
✔
✔
✔
✔
✔
✔
†Include aggregate emissions by gas for domestic and foreign sources separately.
*Reporter may elect to provide detailed emissions data in Schedule I, Section 2, Part B, in which case s/he would not complete Part A.
**Reporter may elect to provide detailed emissions data in Schedule II, Section 2, Addendum, Part B, in which case s/he would not complete Part A.
July 29, 2010
Sec.
2
Voluntary Reporting of Greenhouse Gases
✔
✔
✔
14
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Yes
Yes
No
No
Yes
No
✔*
✔
**
✔
✔*
✔
**
Yes
✔
✔*
✔
**
No
✔
✔*
✔
**
Yes
✔
✔*
✔
✔
**
No
✔
✔*
✔
✔
**
Yes
✔
✔*
✔
✔
**
No
✔
✔*
✔
✔
**
Yes
✔
✔
✔
✔
**
No
✔
✔
✔
✔
**
Yes
✔
✔
✔
**
✔
**
No
✔
✔
Yes
✔
✔
✔
✔
✔
**
No
✔
✔
✔
✔
✔
**
✔
✔
✔
✔
**
✔
✔***
Sec.
3
Subentity Reductions
Rating Summary
✔
No
Sec. 2 & Add. A
Part
Part
Part
A
B
C
Total Emissions and
Carbon Flux for
Subentities
Total Emissions and
Carbon Flux
Yes
Sec.
1
Emissions Inventory
by Source for
Subentities (Add. A)
Emissions Inventory
by Source – Foreign
(Addendum A)
Entity-Level Emission
Reductions
Emissions Inventory
by Source – Domestic
Sec.
4
Emissions Offsets
Aggregated Emissions
by Gas (Domestic and
1
Foreign)
Sec.
3
✔
✔
✔
✔
✔
✔***
✔
✔***
✔
✔
✔
✔
✔
✔
✔***
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
Sec.
2
Sec.
1
Sec.
2
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
✔
✔
****
✔
****
✔
✔
****
✔
✔
****
✔
✔
****
✔
✔
****
✔
✔
****
✔
✔
No
**
****
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
†Include aggregate emissions by gas for domestic and foreign sources separately.
*Reporter may elect to provide detailed emissions data in Schedule I, Section 2, Part B, in which case s/he would not complete Part A.
**Complete Part A if offsets were obtained by agreement with another reporting entity and Part B if offsets were obtained by agreement from a non-reporter.
***Reporter may elect to provide detailed emissions data in Schedule II, Section 2, Addendum, Part B, in which case s/he would not complete Part A.
****Reporters registering reductions using the Change in Emissions Intensity method (Addendum B1) or the Energy Generation and Distribution method (Addendum B5) may also
report but not register reductions using the Change in Absolute Emissions method (Addendum B2). Reporters registering reductions may report but not register reductions of other
indirect emissions and emissions of CFCs.
No
July 29, 2010
Yes
✔
✔
Sec.
1
Self Certification
No
Part
E
Independent
Verification
No
Part
D
Schedule
IV
Reported But not
Registered Reductions
Yes
Sec. 2
Part
C
Schedule
III
Registered Reductions
No
Yes
Part
B
Aggregated Emissions
by Gas for Subentities
(Add. A)
Yes
Part
A
Subentity Statement
Yes
Entity-Wide
Reductions Only?
Foreign Emissions?
All A- or B-rated
Methods?
Independent
Verification?
Report Characteristics
Sec.
1
Entity Statement
Table G4. Decision Chart for a Reporting Year Report for a Large Emitter Intending To Register Reductions
Reporting Requirements
Schedule II
Schedule I
(For Each Subentity)
Voluntary Reporting of Greenhouse Gases
15
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
No
Yes
Yes
No
No
Yes
Yes
No
No
Yes
No
Emissions Inventory
by Source – Domestic
Emissions Inventory
by Source – Foreign
(Addendum A)
Total Emissions and
Carbon Flux
Rating Summary
Emissions Offsets
Entity-Level Emission
Reductions
✔
✔*
✔
No
✔
✔* **
✔
Yes
✔
✔*
✔
No
✔
✔* **
✔
,
,
Yes
✔
✔*
✔
✔
No
✔
✔* **
✔
✔
Yes
✔
✔*
✔
✔
No
✔
✔* **
✔
✔
,
,
Yes
✔
✔**
✔**
✔
No
✔
✔**
✔**
✔
Yes
✔
✔**
✔
No
✔
Sec. 2 & Add. A
Part
Part
Part
A
B
C
✔
✔***
✔
✔
✔***
✔
✔
✔***
✔
✔
✔***
✔
Sec.
3
Sec.
1
Sec.
2
Sec.
1
Self Certification
Aggregated Emissions
by Gas (Domestic and
Foreign) †
Yes
Sec.
1
Independent
Verification
Sec.
4
Reported But not
Registered Reductions
Sec.
3
Schedule
IV
Registered Reductions
Part
E
Schedule
III
Subentity Reductions
Part
D
Total Emissions and
Carbon Flux for
Subentities
Sec. 2
Part
C
Emissions Inventory
by Source for
Subentities (Add. A)
Part
B
Aggregated Emissions
by Gas for Subentities
(Add. A)
Yes
Part
A
Subentity Statement
Yes
Entity-Wide
Reductions Only?
Foreign Emissions?
All A- or B-rated
Methods?
Independent
Verification?
Report Characteristics
Sec.
1
Entity Statement
Table G5. Decision Chart for a Start Year Report for a Small Emitter Intending To Register Reductions
Reporting Requirements
Schedule II
Schedule I
(For Each Subentity)
✔
✔
Sec.
2
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔**
Yes
✔
✔**
✔**
✔
✔
No
✔
✔**
✔**
✔
✔
✔
✔**
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
No
✔
✔**
✔
✔
✔
✔
✔
✔
†Include aggregate emissions by gas for domestic and foreign sources separately.
*Reporter may elect to provide detailed emissions data in Schedule I, Section 2, Part B, in which case s/he would not complete Part A.
**Inventory may be limited to specific activities for which reductions are to be registered. (A small emitter must complete an estimate of entity-wide emissions every five years,
whenever the operations or boundaries of the entity have changed significantly, after any significant increase in emissions, or if its estimated annual emissions exceed 9,000 metric
tons CO2 equivalent. If required, this estimate should be reported in Schedule I, Section 1, Question 3.)
***Reporter may elect to provide detailed emissions data in Schedule II, Section 2, Addendum, Part B, in which case s/he would not complete Part A.
No
July 29, 2010
Yes
Voluntary Reporting of Greenhouse Gases
16
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
No
Yes
Yes
No
No
Yes
No
Rating Summary
Emissions Offsets
Entity-Level Emission
Reductions
Subentity Statement
✔**
✔
No
✔
✔* **
✔*
***
Yes
✔
✔**
✔
***
No
✔
✔* **
✔*
Yes
✔
✔**
✔
✔
No
✔
✔* **
✔
✔
***
Yes
✔
✔**
✔
✔
***
No
✔
✔* **
✔
✔
***
Yes
✔
✔
✔
✔
No
✔
✔*
✔*
✔*
***
Yes
✔
✔
✔
***
✔*
***
,
,
,
,
✔
✔
✔****
✔
✔
✔
✔
***
✔****
✔
✔
✔
No
✔
✔*
✔
✔
✔
✔
✔
No
✔
✔*
✔*
✔*
✔
***
✔
✔
✔
✔
***
Sec.
2
Sec.
1
Sec.
2
✔
*****
✔
✔
✔
*****
✔
✔
✔
*****
✔
✔
✔
*****
✔
✔
✔
*****
✔
✔
*****
✔
✔
✔
✔****
✔
✔
✔
✔
*****
✔
✔
✔
✔****
✔
✔
✔
*****
✔
✔
✔
*****
✔
*****
✔
✔
*****
✔
✔
*****
✔
✔
*****
✔
✔
*****
✔
✔
*****
✔
✔
Yes
Sec.
1
Self Certification
Total Emissions and
Carbon Flux
✔
Sec.
3
Subentity Reductions
Emissions Inventory
by Source – Foreign
(Addendum A)
Yes
Sec. 2 & Add. A
Part
Part
Part
A
B
C
Total Emissions and
Carbon Flux for
Subentities
Sec.
1
Emissions Inventory
by Source for
Subentities (Add. A)
Sec.
4
Aggregated Emissions
by Gas for Subentities
(Add. A)
Sec.
3
Independent
Verification
No
Part
E
Schedule
IV
Reported But not
Registered Reductions
Yes
Part
D
Schedule
III
Registered Reductions
No
Yes
Sec. 2
Part
C
Aggregated Emissions
by Gas (Domestic and
Foreign) †
Yes
Part
B
Entity Statement
Yes
Part
A
Entity-Wide
Reductions Only?
Foreign Emissions?
All A- or B-rated
Methods?
Independent
Verification?
Report Characteristics
Sec.
1
Emissions Inventory
by Source – Domestic
Table G6. Decision Chart for a Reporting Year Report for a Small Emitter Intending To Register Reductions
Reporting Requirements
Schedule II
Schedule I
(For Each Subentity)
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
***
*****
No
✔
✔*
✔*
✔
✔
✔
✔
✔
✔
✔
†Include aggregate emissions by gas for domestic and foreign sources separately.
* Inventory may be limited to specific activities for which reductions are being registered. (A small emitter must complete an estimate of entity-wide emissions every five years,
whenever the operations or boundaries of the entity have changed significantly, after any significant increase in emissions, or if its estimated annual emissions exceed 9,000 metric
tons CO2 equivalent. If required, this estimate should be reported in Schedule I, Section 1, Question 3.)
**Reporter may elect to provide detailed emissions data in Schedule I, Section 2, Part B, in which case s/he would not complete Part A.
***Complete Part A if offsets were obtained by agreement with another reporting entity and Part B if offsets were obtained by agreement from a non-reporter.
****Reporter may elect to provide detailed emissions data in Schedule II, Section 2, Addendum, Part B, in which case s/he would not complete Part A.
*****Reporters registering reductions using the Change in Emissions Intensity method (Addendum B1) or the Energy Generation and Distribution method (Addendum B5) may also
report but not register reductions using the Change in Absolute Emissions method (Addendum B2). Reporters registering reductions may report but not register reductions of other
indirect emissions and emissions of CFCs.
No
July 29, 2010
Yes
✔
✔
✔
Voluntary Reporting of Greenhouse Gases
17
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
No
Yes
Yes
No
No
Yes
Yes
No
No
Yes
No
No
Emissions Inventory
by Source – Domestic
Emissions Inventory
by Source – Foreign
(Addendum A)
Total Emissions and
Carbon Flux
Rating Summary
Emissions Offsets
Entity-Level Emission
Reductions
✔
✔**
✔
No
✔
✔* **
✔
Yes
✔
✔**
✔
No
✔
✔* **
✔
Yes
✔
✔**
✔
✔
No
✔
✔* **
✔
✔
Yes
✔
✔**
✔
✔
No
✔
✔* **
✔
✔
Yes
✔
✔
✔
✔
No
✔
✔*
✔*
✔
Yes
✔
✔
✔
No
✔
✔*
✔
,
,
,
,
Sec. 2 & Add. A
Part
Part
Part
A
B
C
✔
✔***
✔
✔
✔
Sec.
3
Sec.
1
Sec.
2
Sec.
1
Self Certification
Aggregated Emissions
by Gas (Domestic and
Foreign)†
Yes
Sec.
1
Independent
Verification
Sec.
4
Reported But not
Registered Reductions
Sec.
3
Registered Reductions
Part
E
✔
✔
✔
✔***
✔
✔***
✔
✔***
✔
Sec.
2
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
Yes
✔
✔
✔
✔
✔
No
✔
✔*
✔*
✔
✔
Yes
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
No
✔
✔*
✔
✔
✔
✔
✔
†Include aggregate emissions by gas for domestic and foreign sources separately.
*Inventory may be limited to specific activities for which reductions are to be reported but not registered.
**Reporter may elect to provide detailed emissions data in Schedule I, Section 2, Part B, in which case s/he would not complete Part A.
***Reporter may elect to provide detailed emissions data in Schedule II, Section 2, Addendum, Part B, in which case s/he would not complete Part A.
July 29, 2010
Schedule
IV
Subentity Reductions
Part
D
Total Emissions and
Carbon Flux for
Subentities
Sec. 2
Part
C
Emissions Inventory
by Source for
Subentities (Add. A)
Part
B
Aggregated Emissions
by Gas for Subentities
(Add. A)
Yes
Part
A
Subentity Statement
Yes
Entity-Wide
Reductions Only?
Foreign Emissions?
All A- or B-rated
Methods?
Independent
Verification?
Report Characteristics
Sec.
1
Entity Statement
Table G7. Decision Chart for a Start Year Report for All Entities Intending To Report But Not Register Reductions
Reporting Requirements
Schedule
Schedule II
Schedule I
III
(For Each Subentity)
Voluntary Reporting of Greenhouse Gases
✔
✔
✔
18
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
No
Yes
Yes
No
No
Yes
No
No
✔
✔* **
✔
***
Yes
✔
✔**
✔
***
No
✔
✔* **
✔
***
Yes
✔
✔**
✔
✔
No
✔
✔* **
✔
✔
***
Yes
✔
✔**
✔
✔
***
No
✔
✔* **
✔
✔
***
Yes
✔
✔
✔
✔
No
✔
✔*
✔*
✔
***
Yes
✔
✔
✔
***
No
✔
✔*
✔
***
Yes
✔
✔
✔
✔
✔
No
✔
✔*
✔*
✔
✔
***
Yes
✔
✔
✔
✔
***
No
✔
✔*
✔
✔
***
,
,
,
,
✔
✔****
Sec.
1
Sec.
2
Sec.
1
Registered
Reductions
Rating Summary
✔**
✔
Sec.
3
Subentity Reductions
Total Emissions and
Carbon Flux
✔
No
Sec. 2 & Add. A
Part
Part
Part
A
B
C
Total Emissions and
Carbon Flux for
Subentities
Emissions Inventory
by Source – Foreign
(Addendum A)
Yes
Sec.
1
Emissions Inventory
by Source for
Subentities (Add. A)
Emissions Inventory
by Source – Domestic
Sec.
4
Entity-Level Emission
Reductions
Aggregated
Emissions by Gas
(Domestic and
Foreign)†
Sec.
3
Emissions Offsets
Part
E
✔
✔
✔
✔
✔
✔****
✔
✔
✔
✔
✔****
✔
✔
✔
✔
✔****
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
Sec.
2
Self Certification
No
Part
D
Independent
Verification
Yes
Sec. 2
Part
C
Schedule
IV
Reported But not
Registered
Reductions
No
Yes
Part
B
Aggregated
Emissions by Gas for
Subentities (Add. A)
Yes
Part
A
Subentity Statement
Yes
Entity-Wide
Reductions Only?
Foreign Emissions?
All A- or B-rated
Methods?
Independent
Verification?
Report Characteristics
Sec.
1
Entity Statement
Table G8. Decision Chart for a Reporting Year Report for All Entities Intending To Report But Not Register Reductions
Reporting Requirements
Schedule
Schedule II
Schedule I
III
(For Each Subentity)
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
✔
†Include aggregate emissions by gas for domestic and foreign sources separately.
*Inventory may be limited to specific activities for which reductions are to be reported but not registered.
**Optional Reporter may elect to provide detailed emissions data in Schedule I, Section 2, Part B, in which case s/he would not complete Part A.
***Complete Part A if offsets were obtained by agreement with another reporting entity and Part B if offsets were obtained by agreement from a non-reporter.
**** Reporter may elect to provide detailed emissions data in Schedule II, Section 2, Addendum, Part B, in which case s/he would not complete Part A.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
19
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
The information reported on Form EIA-1605 may be treated as confidential if a respondent makes a
written request that its information is financial or commercial information and is confidential or
privileged, and they are able to satisfy the criteria for exemption under the Freedom of Information Act
(FOIA), 5 U.S.C. §552, the DOE regulations, 10 C.F.R. §1004.11, implementing the FOIA, and the Trade
Secrets Act, 18 U.S.C. §1905.
To assist us in this determination, respondents should demonstrate to the DOE that, for example, their
information contains trade secrets or commercial or financial information whose release would be likely
to cause substantial harm to their company's competitive position. A letter accompanying the submission
should explain (on an element-by-element basis) the reasons why reporting this information would be
likely to cause substantial competitive harm if released to the public.
Do You Have Questions or Comments?
If you have questions about the forms and instructions or would like assistance in quantifying your
emissions reductions, please contact the Voluntary Reporting of Greenhouse Gases Program at the above
mailing address or at:
Telephone:
1-800-803-5182
Facsimile:
(202) 586-3045
E-mail:
infoghg@eia.gov
Internet:
http://www.eia.doe.gov/oiaf/1605/index.html
Do You Have Any Suggestions?
You are invited to provide suggestions for improving the form and these instructions. Please limit
comments and suggestions to one page and include them with your submission.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
20
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Specific Instructions for Completing Form EIA-1605
Instructions for Schedule I, Entity Information
Please begin by entering the Reporting Year. The reporting year is the calendar year for which emissions
are being reported. If this is a Start Year report, enter the Start Year, which is the last calendar year of the
initial Base Period.
All reporters must complete Schedule I, Section 1.
Section 1. Entity Statement
1. Enter Entity Identification. Please provide the entity’s legal name and complete address. In
addition, include a website and/or a Tax Payer Identification Number if applicable.
2. Enter Contact Information. Provide the name and complete contact information, including title,
address, telephone number, fax, and email address, of a person who can answer questions regarding
the content of the submitted form. If the contact person’s address is identical to the entity’s address,
please check the relevant box, and leave the Address, City, State, and Zip lines blank. Enter the phone
number, fax, and e-mail address for the contact.
3. Enter Report Characteristics.
a. Report Type. Check the appropriate box to indicate whether this is a Start Year report or a
Reporting Year report. You must submit a Start Year report as the first submission to the
program; subsequent submissions will be Reporting Year reports.
b. Entity Type. Indicate by checking the appropriate box whether your entity is
July 29, 2010
•
a large emitter (annual emissions exceed 10,000 metric tons CO2 equivalent)
intending to register emission reductions.
•
a small emitter (annual emissions are 10,000 metric tons CO2 equivalent or less)
intending to register emission reductions. If this is a Start Year report, enter the
entity’s total estimated entity-wide annual average emissions for Base Period in the
space provided. Small emitters must estimate and report entity-wide emissions in the
Start Year and at least every 5 years thereafter. If this is a Reporting Year report and
a estimate of entity-wide emissions for the Reporting Year and indicate by checking
the appropriate check box the reason the estimate is being submitted. If this report
includes an estimate of entity-wide emissions, indicate how this estimate was
prepared by checking the appropriate box. This entity-wide emissions estimate must
be prepared using either the Simplified Emissions Inventory Tool (SEIT) or methods
specified in Chapter 1 of the Technical Guidelines to estimate entity-wide emissions.
(See “How Do You Determine If Your Are a Small Emitter?” in the General
Instructions for further clarification.)
•
an emitter intending to report but not register emissions and/or emission reductions.
Select the second checkbox under this entity type if you are only reporting emissions
on Form EIA-1605. Emissions-only reporting is not available to entities registering
with the 1605(b) Program.
Voluntary Reporting of Greenhouse Gases
21
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
c. Scope of Inventory. Indicate by checking the appropriate box whether the report contains an
entity-wide or partial inventory. If a partial inventory, indicate which elements of the entity
are included in the inventory in the space provided.
d. Subentities. Indicate by checking the appropriate box whether or not the report includes
subentity reports. List the subentities included in your report in the table provided, giving
each subentity a unique name to distinguish it clearly from the other subentities.
e. Independent Verification. Indicate by checking the appropriate box whether or not an
independent third party has verified the report. If the report has been verified, indicate
whether it includes aggregated emissions data by gas or whether it includes detailed
emissions data by gas and source. While reporting of detailed emissions information is not
required for a verified report, you may opt to provide this information.
4. Indicate Any Significant Changes to Previous Entity Statement. Complete this question if this is a
Reporting Year report. Describe any significant changes your entity has undergone since the previous
year’s report. Check the applicable boxes and provide descriptive information where requested. Skip
this question if this is a Start Year Report.
5. Identify the Entity’s Primary Economic Activities. Enter the primary (and, if applicable, the
secondary) 3-digit North American Industrial Classification System (NAICS) code for the entity. (For
a list of NAICS codes, see Appendix A.)
6. Enter the Entity Category. Check the applicable boxes to describe the entity. If none of the listed
categories applies to your entity, check “Other” and briefly describe the nature of your entity in the
space provided. (Note that an S corporation is a domestic corporation that can avoid double
taxation—once to the shareholders and again to the corporation. Generally, an S corporation is
exempt from federal income tax other than tax on certain capital gains and passive income. See
Internal Revenue Service Publication 583 11 for more information.)
7. Describe the Entity Organization. Use the check box to indicate whether the entity is a holding
company, and if not, enter the name of the entity's Parent or Holding Company if applicable.
8. Describe the Entity’s Organizational Boundaries. Use questions 8a through 8d to define the
organizational boundaries of your entity and to indicate which method was used to draw these
boundaries.
a. Method for Determining Organizational Boundaries. Check the box to indicate your method
for defining the organizational boundaries of your entity. As discussed in the General
Guidelines, the primary basis for defining organizational boundaries should be financial
control, although entities retain the flexibility to use other approaches, such as equity share or
operational control if necessary. For all boundary definition approaches except financial
control, please provide an explanation of the approach. If your entity chooses to use an
approach other than financial control, equity share, or operational control, please check the
“Other” box, list the other method where indicated, and describe how the use of this other
approach results in organizational boundaries that differ from those resulting from using the
financial control approach. Definitions for these Organizational Boundary terms can be found
in the Glossary of Selected Terms.
b. List All Large Wholly Owned Subsidiaries. List all large wholly owned subsidiaries included
in this report, by name and NAICS code. (For a list of NAICS codes, see Appendix A.)
11
Department of the Treasury, Internal Revenue Service, Publication 583, Starting a Business and Keeping Records,
Rev. March 2006, Cat. No. 15150B, p. 3. http://www.irs.gov/businesses/small/article/0,,id=98263,00.html
July 29, 2010
Voluntary Reporting of Greenhouse Gases
22
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
c. List Any Large Partially Owned Subsidiaries, Joint Ventures, and Leased or Operated
Sources. For any large partially owned subsidiary, joint venture, and leased or operated
emissions source included in your report, provide the following information:
•
•
•
•
•
Name or Description of Emissions Source;
Relationship to Entity (subsidiary, joint venture, leased, operated under contract, other);
Partners, Percent Interest Held by Entity;
Method for Determining Inclusion in Report (financial control, equity share, operational
control, other); and
Percentage of Emissions Included in This Report.
d. Additional Description of Organizational Boundaries. Provide any additional description of
organizational boundaries, including criteria used for excluding any emissions sources, if
applicable (pursuant to §300.5(d)(3)(ii) of 10 CFR Part 300, General Guidelines for
Voluntary Greenhouse Gases Reporting).
9. Describe the Geographic Scope of Activities: Check the appropriate box to indicate whether this
report covers only U.S. activities or U.S. and non-U.S. activities. In either case, please also check the
applicable box regarding the scope of your entity’s activities in the U.S. using the following criteria:
Nationwide: Check the box for Nationwide if your entity has operations in at least one state in
each of the 9 U.S. Census Divisions. The U.S. Census Divisions are identified in Appendix B.
Multiple States: Check the box for Multiple States if your entity has operations in more than one
State but does not meet the criteria for Nationwide. List the States in which your entity has
operations using the two-letter abbreviations listed in Appendix B.
Single State: Check the box for Single State if your entity has operations in only one State.
Identify the state in the space provided using the two-letter abbreviations listed in Appendix B.
If this report covers U.S. and Non-U.S. activities, please also list all foreign countries in which
reported activities occurred, and using the 3-digit codes found in Appendix C, enter the NAICS code
that best corresponds to the primary activity of the operations in each country.
10. Describe the Scope of Emissions Inventory: If your report includes an emissions inventory, check
the applicable box for each of the emissions sources included.
11. Describe the Entity Base Period: Check the box indicating the number of years in the Base Period,
and enter the last year in Base Period. Also, if you are reporting subentities that use a different base
period from the entity, please check the box where indicated.
12. Describe Any Entity Program Affiliation(s): Using the codes referenced in Appendix D, list any
domestic or foreign initiatives, registries, and exchanges with which the entity has an affiliation. If
you are a participant in a program not specified in Appendix D, please list program affiliations under
“Other.”
13. Request Confidentiality of Entity Information: If your report contains information you deem
confidential please check the box. Checking this box will alert EIA that you are seeking to have your
entire report classified as confidential and not be made publicly available. Use the space provided to
explain, on an element-by-element basis, the reasons why your report should be made confidential.
The information contained in the report will be kept confidential and not disclosed to the public to the
extent that it satisfies the criteria for exemption under the Freedom of Information Act (FOIA), 5
USC §552; the DOE regulations, 10 CFR §1004.11, implementing the FOIA; and the Trade Secrets
Act, 18 USC §1905.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
23
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
14. Enter Supplementary Information for Entity: Use this space to provide any supporting
information you feel should be included in your entity’s report. Attach additional sheets if necessary.
Section 2. Entity Emissions Inventory
Use Section 2 to report the emissions inventory for your entity. All large emitters intending to register
reductions are required to complete an entity-wide emissions inventory using methods that meet the
quality requirements established by §300.6(b) of 10 CFR Part 300, Guidelines for Voluntary Greenhouse
Gas Reporting. Small emitters intending to register emission reductions must submit at least an inventory
of the portion or portions of their entity associated with each of the activities associated with registered
emission reductions. Entities intending to report but not register reductions may choose to report their
emissions inventory on an entity-wide basis or for selected elements of their entities, selected gases, or
selected sources.
Check the box at the beginning of Section 2 if all methods used to estimate emissions and sequestration
have a B rating or higher. If the box is checked, do not complete “Weighted Rating” column of Parts A,
B, C, and D and skip Part E completely.
Part A. Aggregated Emissions by Gas (for Independently Verified Reports Only)
1. Enter Aggregated Emissions by Gas (for independently verified reports only). If your report has
been independently verified, you may limit your inventory report to emissions by gas and source
(direct emissions, indirect emissions from purchased energy, and carbon fluxes). For each Item (A1
through G) defined by source (Column 2) and gas (Column 3), enter the following in the data table
provided in Part A, Question 1:
•
•
•
•
Units (Column 4). Enter the units (i.e., kilograms, metric tons) for the gas quantities reported in
Column 4.
Base Period Emissions or Carbon Flux (Columns 5-9). If this is a Start Year report, enter the
emissions for Base Period years 1 through 4 in Columns 5-8. Calculate and enter the Base Period
Average emissions by summing the emissions for years 1 through 4 and dividing by the number
of years in the Base Period. Enter the result in Column 9. If this is a Reporting Year report,
complete Columns 5-9 only if the Base Period emission data have been revised to correct errors
or to reflect changes to the entity, such as acquisitions and divestitures.
Reporting Year Emissions or Carbon Flux (Column 10). If this is a Reporting Year report,
enter the Reporting Year emissions or carbon flux in Column 10. If this is a Start Year report,
leave Column 10 blank.
Weighted Rating (Column 11). Calculate and enter the emission-weighted rating for each item
using the equation below. If this is a Start Year report, the weighted rating should be based on the
Base Period Average emissions. If this is a Reporting Year report, the weighted rating should be
based on Reporting Year emissions.
RW = [(EA * 4) + (EB * 3) + (EC * 2) + (ED * 1)] / (EA + EB + EC + ED)
Where RW = Weighted Rating
EA = Emissions from sources estimated with an A-rated method
EB = Emissions from sources estimated with an B-rated method
EC = Emissions from sources estimated with an C-rated method
ED = Emissions from sources estimated with an D-rated method
July 29, 2010
Voluntary Reporting of Greenhouse Gases
24
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Enter the above emissions data for the following sources in the appropriate rows of the data table
provided:
•
•
•
•
•
•
•
Direct Emissions (Items A1-A7). Enter direct emissions of carbon dioxide under Item A1, direct
methane emissions under Item A2, direct nitrous oxide emissions under Item A3, and direct sulfur
hexafluoride emissions under Item A4. If you are entering direct emissions of HFCs, PFCs, and
CFCs, specify the gas in Column 3 using the codes provided in Appendix E and enter the values
under Items A5-A7. If you wish to enter data for more than four gases in the Other Greenhouse
Gas category, complete and attach additional copies of this data table.
Indirect Emissions of CO2 From Purchased Energy (Inventory), (Items B1-B3). Enter
indirect emissions of CO2, CH4, and N2O from Purchased Energy under Items B1, B2, and B3,
respectively. Use the electricity end-use factors for emission inventories from Appendix F to
calculate Items B1-B3.
Indirect Emissions of CO2 From Purchased Energy (Reductions), (Item C). Enter indirect
emissions from Purchased Energy under Item E in metric tons CO2e. Use the electricity end-use
factors for emission reductions from Appendix F to calculate Item C. Only complete this item if
you are calculating reductions at the entity level using Addendum B1 or B2.
Carbon Flux (Item D). Enter carbon flux under Item D in units of carbon dioxide. Enter positive
flux (increases in carbon stored in a carbon sink) as negative values (i.e., negative emissions).
Other Indirect Emissions (Items E1-E7). Enter other indirect emissions of carbon dioxide
under Item E1, other indirect methane under Item E2, other indirect nitrous oxide emissions under
Item E3, and sulfur hexafluoride under Item E4. If you are entering indirect emissions of other
gases (HFCs, PFCs, or CFCs), specify the gas in Column 3 using the codes provided in Appendix
E and enter the values under Items E5-E7. If you wish to enter data for more than four gases in
the Other Greenhouse Gas category, complete and attach additional copies of this data table.
Captured CO2 Sequestered in an Onsite Geologic Reservoir (Item F). Enter the quantities of
CO2 sequestered in an onsite geologic reservoir. Report emissions in carbon dioxide equivalents
if you want to include the trace quantities of methane or nitrous oxide in the captured CO2.
Captured CO2 Transferred to Another Entity for Sequestration in a Geologic Reservoir
(Item G). Enter the quantities of CO2 transferred to another entity for storage in a geologic
reservoir under Item G. Report emissions in carbon dioxide equivalents if you want to include the
trace quantities of methane or nitrous oxide in the captured CO2.
2. Enter Aggregated Foreign Emissions by Gas (for independently verified reports only). Use the
instructions for Question 1 to complete Question 2 if your entity includes foreign operations.
Part B. Inventory of Emissions and Carbon Flux
Complete Part B if you are a large emitter that is registering reductions and your report has not been
independently verified. Each small emitter and large emitter intending to report but not register
reductions, if their report has not been independently verified, should also complete Part B, at a minimum,
for those activities for which they are registering reductions. Small emitters and large emitters intending
to report but not register reductions, if required to complete Part B, can, at their option, complete the
emissions inventory for all emission sources, not just those relative to activities submitted for registered
reductions.
The data tables comprising the entity-level emissions inventory in Part B, Questions 1 through 3 have a
similar structure. The following instructions provide general guidance for completing the columns of each
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
of these tables. These instructions are followed by specific instructions for completing the line items in
each table.
General Instructions for Part B
For each of your entity’s emission sources, as defined by Source Category (Column 1), Fuel Type
(Column 1A), Specific Facility/Source Name (optional) (Column 2), Gas (Column 3), and Estimation
Method (Column 11), enter the information below in the remaining columns in the emissions data tables.
If you have more emission sources than can be accommodated in the rows provided in any table, make
one or more additional copies of that table, enter the data, and attach the copy or copies to your
submission.
•
Fuel Type (Column 1A). For stationary combustion and mobile sources only (Q. 1a), identify
the fuel used by each source using the codes in Table 3 below:
Table 3. Fuel Codes for Reporting Emissions
from Stationary Combustion and Mobile
Sources
Fuel
Code
Stationary Combustion
Coal
CL
Liquid Petroleum Fuels
PT
Liquid Petroleum Gases
PG
Natural Gas
NG
Petroleum Coke
PC
Refinery (Still) Gas
RG
Petroleum-Based Waste Fuels
WP
Municipal Solid Waste
MW
Biomass
BM
Unspecified
US
Mobile Sources
Gasoline
GS
Biodiesel
BD
Diesel
DS
Natural Gas
NG
Propane
PR
Ethanol
ET
Methanol
MT
Unspecified
US
•
•
•
Units (Column 4). Enter the units (i.e., kilograms, metric tons) in Column 4 for the gas quantity
reported in subsequent columns.
Base Period Emissions (Columns 5-9). If this is a Start Year report, enter the emissions for Base
Period years 1 through 4 in Columns 5-8. Calculate and enter the Base Period Average emissions
by summing the emissions for years 1 through 4 and dividing by the number of years in the Base
Period. Enter the result in Column 9. If this is a Reporting Year report, complete Columns 5-9
only if the Base Period emission data have been revised to correct errors or to reflect changes to
the entity, such as acquisitions and divestitures.
Reporting Year Emissions (Column 10). If this is a Reporting Year report, enter the Reporting
Year emissions or carbon flux in Column 10. If this is a Start Year report, leave Column 10
blank.
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U.S. Department of Energy
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Form EIA-1605
•
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Estimation Method (Column 11). Identify the method in Column 11 used to estimate the
emissions for each item using the codes listed in Appendix G. Note that you must report
emissions estimated using different methods separately.
Rating (Column 12). Enter the numeric rating for the method(s) used to estimate each emissions
source, where A = 4, B = 3, C = 2, and D = 1. If this is a Start Year report, the rating should be
based on the Base Period Average emissions. If this is a Reporting Year report, the rating should
be based on Reporting Year emissions, even if you have revised Base Period emissions.
Specific Instructions for Part B
1. Enter Direct Emissions
a. Stationary Combustion. For this section of the form, enter information on emissions from the
following four categories—“Fossil Fuel Combustion,” “Nonstandard Fuel Combustion,” “Waste
Fuels Combustion,” “Biomass Combustion,” and “Nonfuel Use of Fossil Fuels.” You may
aggregate emissions by fuel type provided you use the same estimation method for each fuel type.
However, if you prefer to report emissions disaggregated by facility or source, you may do so
provided you enter a unique name for the facility or source in Column 2.
CO2 from stationary combustion that is captured and stored in an onsite reservoir must be
identified in your emissions inventory but excluded from total inventory emissions.
Follow the General Instructions in Part B above to fill out the different columns for each of the
following fuel sources:
Fossil Fuel Combustion. The following fuel types should be included in this category—coal,
natural gas, middle distillates, heavy fuel oil, and liquefied petroleum gases (LPG). Specific
directions for estimating CO2 emissions from the stationary combustion of coal can be found in
section 1.C.3.1 of the Technical Guidelines. Here you will find the ratings for different estimation
methods along with some default emissions factors for different types of coal. Similar
information can be found for natural gas (1.C.3.2), middle distillates and heavy fuel oil (1.C.3.3),
and LPG (1.C.3.4) in the Technical Guidelines. Estimation methods, ratings, and generic
emissions factors for methane (CH4) and nitrous oxide (N2O) emissions from coal, petroleum, and
natural gas can be found in section 1.C.4— “Common Sources: Methane and Nitrous Oxide” of
the Technical Guidelines.
Nonstandard Fuel Combustion. Greenhouse gas emissions from the direct stationary combustion
of nonstandard fuels should include emissions from the following fuels: refinery gas (1.C.5.1),
petroleum coke (1.C.5.2), and natural gas / crude oil flaring (1.C.5.3). See the referenced sections
of the Technical Guidelines for estimation method ratings and default emissions factors (in most
cases) for each fuel type.
Waste Fuels Combustion. Direct emissions from waste fuels include the combustion of a range
of specialized waste and by-product fuels, including used lubricating / motor oil and used tirederived fuel. Emissions factors and ratings for these fuel types can be found in section 1.C.5.4,
“Petroleum-Based Waste and By-Product Fuels,” of the Technical Guidelines.
Biomass Combustion. Greenhouse gas emissions from the combustion of biomass are described
in the sections for biogenic fuels (1.C.5.5) and municipal solid waste and landfill gas (1.C.5.6) of
the Technical Guidelines. CO2 emissions from biogenic fuels, including bagasse, wood, wood
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Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
waste, ethanol, black liquor, and municipal greenwaste, should be omitted from your emissions
inventory as they are not considered to be anthropogenic emissions. Thus, only the CO2 emissions
resulting from the combustion of material of anthropogenic origin in municipal solid waste (e.g.
plastics) must be included in your inventory (under Waste Fuels Combustion). However, biomass
combustion yields emissions of CH4 and N2O, which should be reported.
Nonfuel Use of Fossil Fuels. There are a number of applications where fossil fuels are not
combusted directly, but are used for industrial purposes. These applications include:
•
•
•
•
•
Lubricants, asphalt, and petroleum-based solvents;
Natural gas, LPG, and petroleum products as chemical feedstocks;
Coke and related products as reducing agents in metals manufacture;
Fossil fuels as a carbon source in products (e.g. carbon black); and
Transformation of lower value hydrocarbon into a higher value hydrocarbon (synthetic
fuels).
Where possible, these emissions should be reported elsewhere in the form (i.e. Schedule I,
Section 2, Part B, Question 1c, Sector-Specific Industrial Process Emissions). In these special
situations it is the reporter’s responsibility to accurately calculate a material balance. This process
should enable the reporter to identify whether the non-fuel use of the fossil fuel is sequestering,
non-sequestering, or partially sequestering. Generally, carbon that is sequestered in a product is
not a reportable emission. More detail on how to calculate these emissions, along with ratings for
different estimation methods, are described in section 1.C.6 of the Technical Guidelines.
Subtotal. Using the Global Warming Potential (GWP) values found in Appendix E, convert your
Base Period emissions and Reporting Year emissions into units of carbon dioxide equivalent
(CO2e). Sum those CO2e values for each column 4 through 9 and place the totals at the bottom of
each column in the Subtotal row. It is not necessary to include an estimation method or rating in
this row.
b. Mobile Source Combustion. Mobile source greenhouse gas emissions include carbon dioxide
(CO2), methane (CH4), and nitrous oxide (N2O) from fuel combustion, and hydrofluorocarbons
(HFC) from mobile air-conditioning and refrigeration system leakage. Sources include highway
vehicles, off-road vehicles, water borne vessels, aircraft, and mobile refrigeration and airconditioning units.
To date there have been no carbon dioxide capture projects involving mobile sources, but if any
of a reporter’s carbon dioxide emissions from mobile sources were subsequently captured for
storage in a geologic reservoir, the reporter should include these quantities in the emissions total
by fuel source category. In addition, the reporter should document the quantity of carbon dioxide
emissions that were captured in Question 1f, Captured CO2 Emissions. Use Addendum B8 to
report reductions associated with capturing CO2 and storing it in a geologic reservoir.
For mobile sources, the mass balance method is most frequently used for estimating carbon
dioxide and HFC emissions based on fuel combustion and refrigerant use, respectively. Methane
and nitrous oxide emissions are commonly estimated by inference using activity data (e.g.,
distance traveled or fuel consumption) and emission factors developed from sample emissions
measurement. Inferred emissions can generally be expected to be less accurate, but are acceptable
for estimating minor emissions from methane and nitrous oxide. Mass balance or inference
methods may be used to estimate HFC emissions resulting from leakage.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
For more information on emissions from mobile sources, see Chapter 1, Part D of the Technical
Guidelines. For source-specific guidance on estimating emissions, see section 1.D.3 of the
Technical Guidelines.
Follow the General Instructions in Schedule I, Section 2, Part B of this document to fill out the
information requested for Columns 4 through 12 for each of the following sources:
Highway Vehicles. This category includes a variety of vehicles such as on-road and light- and
heavy-duty vehicles, which consume a number of different fuels. Within this category, on-road
light- and heavy-duty vehicles using conventional fuels (gasoline or diesel) include: passenger
vehicles, hybrid-electric vehicles, motorcycles, light-duty trucks (vans, pick-up trucks and sport
utility vehicles), heavy-duty trucks (delivery trucks), and buses. Also included in this category are
on-road vehicles using alternative fuels (e.g., compressed natural gas, propane, methanol), which
include passenger vehicles, light-duty trucks, heavy-duty trucks, and buses.
Off-Road Vehicles. The off-road vehicle category includes a wide variety of vehicles operating
on conventional fuels such as gasoline, diesel, and fuel oil. Vehicles within this category include:
construction equipment, agricultural equipment, off-road recreational vehicles, snowmobiles, and
diesel locomotives. Most off-road vehicles will burn un-taxed (red-dyed) diesel fuel (off-highway
No. 2-D), which is generally very similar to the taxed fuel, while locomotives use a special
“railroad” diesel. Conventional snowmobiles and some other recreational off-road vehicles have
two-stroke spark-ignition engines that burn a gasoline-lubricant mixture, though some relatively
new snowmobiles may operate using four-stroke spark-ignition engines that combust gasoline
only.
Water Borne Vessels. Water borne vessels include recreational boats, patrol boats, cruise ships,
large freight vessels, container ships, and many other types of vessels with various purposes. In
general, very small boats (often less than 50 feet in length) have spark ignition inboard, sterndrive
(inboard/outboard or inboard/outdrive), or outboard engines that burn gasoline. Some boats less
than 50 feet in length may have inboard compression ignition (i.e., diesel-cycle) engines that burn
diesel fuel or another distillate, residual or intermediate blend. Nearly all commercial shipping
vessels and cruise ships have large diesel engines that burn residual fuel or an intermediate
distillate-residual blend, but it is possible that some of these compression ignition engines burn a
kerosene-based fuel. Some ships (especially high-speed ferries and military vessels) have gas
turbine engines that burn kerosene-based jet fuel.
Aircraft. This category includes all aircraft running on kerosene jet fuel and non-jet-engine planes
that burn aviation gasoline, or less commonly, motor gasoline. The vehicle types include turbineand piston-engine-driven aircraft, turbine-powered transport and air cargo aircraft. Within this
category, reporters will consider all civil commercial uses of airplanes (international and
domestic) consisting of scheduled and chartered flights for passengers and freight. This category
also includes civil commercial use of airplanes and helicopters for agricultural purposes,
instructional flying, business and pleasure flying, aerial work, and other flying.
Mobile Refrigeration and Air-Conditioning. This source refers to mobile refrigeration and airconditioning units, with emissions of HFC-134a from leakage.
Subtotal. Using the Global Warming Potential (GWP) values found in Appendix E, convert your
Base Period emissions and Reporting Year emissions into units of carbon dioxide equivalent
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Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
(CO2e). Sum those CO2e values for each column 5 through 10 and place the totals at the bottom
of each column in the Subtotal row. It is not necessary to include an estimation method or rating
in this row.
c. Sector-Specific Industrial Process Emissions. Entities that have emissions from any type of
industrial process should provide their emissions data in the table provided. Reporters should
ensure that the same emissions are not “double counted,” or recorded elsewhere in Schedule I,
Section 2, Part B. In particular, where the primary purpose of an industrial process is energy
production (in the form of heat or electricity), emissions should be attributed to stationary
combustion (see Schedule I, Section 2, Part B, Question a, Stationary Combustion).
Carbon dioxide captured from industrial process sources and stored offsite must be treated as an
emission in the emissions inventory of the entity within which the capture occurs. Captured CO2
emissions stored in an onsite reservoir must be identified in your emissions inventory but should
be excluded from total inventory emissions. If this captured CO2 was subsequently stored in a
geologic reservoir, the reporter should document the quantity of CO2 emissions captured in
Question 1f, Captured CO2 Emissions and use Addendum B8 to report reductions associated with
capturing CO2 and storing it in a geologic reservoir.
Reporters should include all substantial process emissions and fugitive emissions resulting from
their industrial processes. Reporters need not include sources determined to be de minimis, which
are sources that, in aggregate, are less than or equal to 3 percent of the total annual carbon dioxide
equivalent emissions of the entity. De minimis emissions must be recorded in Section 2, Part B,
Question 5.
For more information on sources of process and fugitive emissions see Chapter 1, Part E of the
Technical Guidelines. For sector-specific guidance on estimating process and fugitive emissions,
see section 1.E.4 of the Technical Guidelines.
Follow the General Instructions in Schedule I, Section 2, Part B above to fill out the information
requested in Columns 5 through 12 for each of the following sources:
Industrial Processes
Adipic Acid Production. Adipic acid is a white, crystalline powder used primarily for the
manufacture of synthetic nylon fibers. Adipic acid is also used in the production of gelatins,
beverages, oils, snack foods, plasticizers for polyvinyl chloride and polyurethane resins, wire
coatings, adhesives, lubricants and dyes. Nitrous oxide (N2O) is the primary greenhouse gas
emitted during the production of adipic acid and is pre-entered on Form EIA-1605.
Aluminum Production (CO2 only). Aluminum is produced through a complex set of processes,
some of which generate emissions. A number of these processes can be completed using different
technologies, each of which may feature more than one emission estimation method. Reporters
should begin by familiarizing themselves with the types of facilities (and their accompanying
processes) for which they will be estimating emissions. Greenhouse gases emitted from the
various processes include carbon dioxide resulting from the oxidation of carbon electrodes in an
electrolytic process. (Enter emissions of perfluorocarbons sulfur hexafluoride and under
Aluminum Production in the High GWP Gases section of this table.)
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
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Form EIA-1605
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Form Approved
OMB No. 1905-0194
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Ammonia Production. Most ammonia (NH3) production processes emit carbon dioxide through
the catalytic reformation of fossil fuels. Carbon dioxide (CO2) is the primary greenhouse gas
emitted during the production of ammonia and is pre-entered on Form EIA-1605.
Cement Production – Clinker Production. Cement production releases carbon dioxide during the
production of clinker (from the calcination of limestone). Carbon dioxide (CO2) is the primary
greenhouse gas emitted during this process and is pre-entered on Form EIA-1605.
Cement Production – Cement Kiln Dust. Cement production also releases carbon dioxide from
discarded bypass and/or cement kiln dust (CKD). Again, carbon dioxide (CO2) is the primary
greenhouse gas emitted during this process and is pre-entered on Form EIA-1605.
Hydrogen Production. Hydrogen is similar, in many respects, to ammonia production. As in the
case of ammonia, a hydrocarbon feedstock (usually natural gas) is reformed into a carbon
monoxide-hydrogen synthesis gas. In this case, the hydrogen is separated and used for other
purposes (usually to boost light product output in oil refineries, occasionally directly as a
transportation fuel). Reporters should only treat carbon dioxide produced as a byproduct of
hydrogen production as an industrial process emission if it is emitted into the atmosphere. Carbon
dioxide (CO2) is the primary greenhouse gas emitted during the production of hydrogen and is
pre-entered on the form.
Iron and Steel Production. The majority of carbon dioxide emissions from iron and steel
production are generated during the consumption of the reducing agent and of additives (typically
plastics) used to minimize the quantity of reducing agent used. Consumption of carbonate fluxes
is also a significant source of carbon dioxide, but these emissions should be calculated using the
methods outlined under “Limestone and Dolomite Use.” Carbon dioxide (CO2) is the primary
greenhouse gas emitted during the production of iron and steel and is pre-entered on Form EIA1605. Enter the CO2 emissions for your entity under one or more of the following iron and steel
processes:
• Iron and Steel Production – All Processes
• Iron and Steel Production – Reducing Agents
• Iron and Steel Production – Furnace Additives
• Iron and Steel Production – Crude Iron Production
• Iron and Steel Production – Conversion of Iron to Steel
• Iron and Steel Production – Electrode Consumption in Electric Arc Furnaces
• Iron and Steel Production – Secondary Steel Production in Electric Arc Furnaces
• Iron and Steel Production – Other
Methane is also produced in iron and steel production and should be reported in Question 1c,
Other Iron and Steel.
Lime Production. Lime production refers to the manufacture of high calcium lime, dolomitic
lime, and hydraulic lime. In all three processes, carbon dioxide is released by thermally
decomposing, or “calcining,” calcium carbonate (CaCO3) into lime (CaO) and carbon dioxide.
Calcining calcium carbonate produces high calcium and hydraulic lime, while dolomitic lime is
produced by the calcination of dolomite. Reporters need not include carbon dioxide from the
Kraft pulping process of lime production in their emissions inventories, as the carbon dioxide
released is a biogenic source. Carbon dioxide (CO2) is the primary greenhouse gas emitted during
the production of lime and is pre-entered on Form EIA-1605.
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Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Limestone and Dolomite Use. The method for estimating carbon dioxide emissions from
limestone use (see above) is largely analogous to that used to estimate emissions from lime
production. The primary difference between the methods is that estimates for lime production are
based on the quantity of the calcium-bearing product whereas emissions from limestone and
dolomite use are estimated using the quantity of calcium-bearing raw materials. Carbon dioxide
(CO2) is the primary greenhouse gas emitted during the use of lime and dolomite and is preentered on the form.
Methanol Production. Methanol production is similar to ammonia production (see above), in that
methanol production begins with reforming of a hydrocarbon feedstock (usually natural gas) into
a carbon monoxide-hydrogen synthesis gas. In this case, however, most of the carbon is
embodied in the product (CH3OH). Methanol in the United States is mostly used as a gasoline
additive, though there is also a large market for methanol as a chemical feedstock. Carbon
dioxide (CO2) is the primary greenhouse gas emitted during the production of methanol and is
pre-entered on Form EIA-1605.
Methane Emissions From Production of Other Petrochemicals. The production of carbon black,
ethylene, ethylene dichloride, and styrene all generate small amounts of methane emissions.
Nitric Acid Production. Nitric acid (HNO3) is an important primary ingredient of nitrogen-based
synthetic fertilizers. Other important applications include adipic acid production, production of
explosives, metal etching, and processing of ferrous metals. The primary greenhouse gas emitted
from the production of nitric acid is nitrous oxide. Nitrous oxide is released during the high
temperature catalytic oxidation of ammonia (NH3). In addition to nitrous oxide, this oxidation
reaction can also generate smaller quantities of non-combustion oxides of nitrogen (NOx). Nitrous
oxide (N2O) is the primary greenhouse gas emitted during the production of nitric acid and is preentered on Form EIA-1605.
Soda Ash Production. There are four manufacturing processes employed to produce soda ash
(Na2CO3): monohydrate carbonation, sesquicarbonate carbonation, direct carbonation, and the
Solvay process. The first three of these processes, which account for about 25 percent of world
soda ash production, generate carbon dioxide emissions during the chemical transformation of the
naturally occurring ore, trona, into soda ash. The Solvay process, which synthesizes soda ash
from a series of materials and reactions, generates no direct carbon dioxide emissions. Emissions
from stationary combustion and the use of coke to facilitate these processes, however, should be
estimated and should be accounted for separately. Carbon dioxide (CO2) is the primary
greenhouse gas emitted during the production of soda ash and is pre-entered on Form EIA-1605.
Soda Ash Use. Carbon dioxide (CO2) is emitted during the use of soda ash in flue gas
desulfurization and various manufacturing processes, including those for glass, soap, and
detergents.
Energy
Coal Mines. The principal greenhouse gas associated with coal mining is methane. Carbon
dioxide and nitrous oxide are also emitted but in relatively small amounts. Methane is created in
the same geologic processes that produce coal, and therefore exists in varying degrees in all coal
deposits. The methane is stored in the coal pores (open spaces) and in the cracks and fractures
within the coal bed. Carbon dioxide is also emitted directly from the combustion of fossil fuels by
mining equipment or indirectly from the consumption of electricity and should be estimated and
reported according to the Technical Guidelines in Chapter 1, Parts C (Stationary Combustion).
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
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Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Methane (CH4) is pre-entered on Form EIA-1605 as this section should focus exclusively on
estimating methane emissions from coal mining.
Oil and Natural Gas Industries. Methane is the principal non-combustion greenhouse gas
emitted by both the natural gas and oil industries. The majority of emissions from the both
industries are fugitive methane emissions from production processes. Carbon dioxide emissions
can be emitted in significant quantities from a limited number of processes, such as sour gas
processing, or in instances where natural gas streams are particularly rich in carbon dioxide.
Nitrous oxide is also emitted from a number of activities, but usually in relatively low
concentrations. Methane (CH4), carbon dioxide (CO2) and nitrous oxide (N2O) emissions are all
associated with the oil and natural gas industries and are pre-entered on Form EIA-1605.
Waste Handling
Domestic and Industrial Wastewater Handling. The wastewater streams most likely to produce
significant methane emissions are those that are rich in organic matter, including domestic
wastewater as well as wastewater streams from the pulp and paper manufacturing industries, meat
and poultry packing industries, and vegetable, fruit and juice processing industries. Wastewater
can also be generated during the manufacture of textiles, petrochemical products, fertilizers, iron
and steel, and organic chemicals. Domestic wastewater streams will also generate nitrous oxide
emissions. Nitrous oxide is released as a byproduct of two processes: nitrification and
denitrification. Methane (CH4) and nitrous oxide (N2O) are the primary greenhouse gases emitted
during the treatment of wastewater and have been pre-entered on Form EIA-1605.
Landfills. Methane is released from landfills through the anaerobic decomposition of organic
wastes such as paper, food, and yard waste, and accounts for 30 to 60 percent of all gases emitted
from landfills. The balance of gases includes primarily carbon dioxide and other minor
constituents such as nitrogen, volatile organic compounds, and water vapor. The capture and
combustion of landfill gas is a common practice used to mitigate methane and other air pollutants
in the gas. Methane (CH4) is pre-entered on Form EIA-1605, as this section should focus
exclusively on estimating methane emissions from landfills.
High GWP Gases
Aluminum Production. Aluminum is produced through a complex set of processes, some of
which generate emissions. A number of these processes can be completed using different
technologies, each of which may feature more than one emission estimation method. Reporters
should begin by familiarizing themselves with the types of facilities (and their accompanying
processes) for which they will be estimating emissions. Greenhouse gases emitted from the
various processes include carbon dioxide, perfluorocarbons (PFCs) and sulfur hexafluoride.
Identify the specific PFCs that were emitted in Column 2 using the greenhouse gas codes from
Appendix E.
HCFC-22 Production. Trifluoromethane (HFC-23) is a high GWP greenhouse gas that is
generated as a byproduct during the manufacture of chlorodifluoromethane (HCFC-22). Unlike
the majority of HFC emissions, most HFC-23 emissions are point-source emissions, emitted
through the condenser vents of HCFC-22 manufacturing plants. Some HCFC-22 manufacturers
may capture some of the HFC-23 byproduct and sell it for use in various applications from which
it is eventually emitted. Captured HFC-23 should not be included in the inventory of the entity
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U.S. Department of Energy
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
(though the entity should always report all process, fugitive and other emissions associated with
its manufacture).
SF6 Emissions From Electrical Equipment. Sulfur hexafluoride (SF6) has various uses and
emissions associated with electrical equipment. Include in the emissions inventory any SF6
emissions associated with electrical equipment, generation, transmission and distribution.
Industrial Use and Production of HFCs, PFCs, and SF6. HFCs, PFCs, and SF6 are used as
substitutes for ozone depleting substances and in a wide variety of industrial processes. Industrial
uses of HFCs and PFCs include the manufacture and use of refrigeration and air-conditioning,
fire suppression and explosion protection, aerosol manufacture and use, solvent cleaning, foam
blowing, equipment sterilization, and the manufacture of coatings, adhesives and inks. SF6 is
commonly used to insulate switchgear and circuit breakers (for explosion protection) in
semiconductor manufacture and aluminum and magnesium foundries. With the exception of PFC
emissions from aluminum and HFC-23 emissions from HCFC-22 manufacture, emissions of
HFCs, PFCs, and SF6 are largely fugitive emissions associated with the prior purchase of
manufactured chemicals by these industries.
Magnesium Production. Sulfur hexafluoride is used as a cover gas to prevent the oxidation of
molten magnesium during smelting, casting, and other production processes. It is generally
accepted that none of the sulfur hexafluoride is consumed in this process, and that it is all emitted
directly into the atmosphere after use. The amount of sulfur hexafluoride emitted during
magnesium production is thus equal to the amount consumed. SF6 has been pre-entered on Form
EIA-1605.
Semiconductor Manufacture. The semiconductor manufacturing industry emits a variety of high
global warming potential gases, including PFCs (CF4, C2F6, C3F8, and c-C4F8), HFCs (CHF3), and
sulfur hexafluoride (SF6). The relative quantity of each gas emitted (referred to collectively as
fluorinated compounds, FCs) is site-specific, and depends on the processes employed, the
machinery, and the specifications of the manufacturing process. In general, though, FCs are
emitted from two distinct processes: plasma etching and chemical vapor deposition (CVD).
Identify the specific FCs that were emitted using the greenhouse gas codes from Appendix E.
Enter any other industrial processes occurring within your entity’s boundary that produce
emissions. Record the emissions of all greenhouse gases under the correct pre-entered greenhouse
gas line item. Identify the specific PFCs and HFCs, if any, were emitted using the greenhouse gas
codes from Appendix E.
Other. Include any other emissions associated with industrial processes that are not included in
the above categories. Report these emissions by gas in the rows provided. Specify the gas for
emissions of PFCs, HFCs, and CFCs.
Subtotal. Using the Global Warming Potential (GWP) values found in Appendix E, convert your
Base Period emissions and Reporting Year emissions into units of carbon dioxide equivalent
(CO2e). Sum those CO2e values for each column 4 through 9 and place the totals at the bottom of
each column in the Subtotal row. It is not necessary to include an estimation method or rating in
this row.
d. Agricultural Sources. Entities with agricultural operations should provide their emissions data in
the table provided. The various sources listed are associated with keeping livestock, crop
production, and soil management. Greenhouse gases emitted from these sources can be CO2, CH4,
and N2O. To report sources not included, use the “Other” row.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Follow the general instructions in Schedule I, Section 2, Part B for completing Columns 3
through 11 in the data table. Instructions pertaining to the specific sources are provided below.
Enteric Fermentation. CH4 is produced as a byproduct of normal animal digestion through
“enteric fermentation.” Enteric fermentation results from the breakdown of food by microbes that
release CH4, which is then emitted from the animal to the atmosphere through exhaling or
eructation. Ruminant livestock (including cattle, sheep, and goats) have greater rates of enteric
fermentation than non-ruminant livestock (such as swine, horses, and mules).
Livestock Waste. CH4 and N2O emissions from waste are caused by the biological breakdown of
organic matter in the waste. Livestock waste can be managed with storage and treatment systems,
or spread daily on fields in lieu of long-term storage. In some cases, livestock waste is
“unmanaged” and left on or in the pastures, ranges, or paddocks where the animals graze.
Residue Burning. Burning crop residues and native vegetation is not considered to be a
significant source of carbon dioxide released in the United States. Carbon dioxide released during
burning is generally taken up by vegetation the following growing season and is not considered a
source of anthropogenic carbon dioxide emissions. However, field burning of crop residues emits
nitrous oxide and methane that are considered anthropogenic emission sources and should be
reported.
Rice Cultivation. Most rice grown in the United States is cultivated on shallow, continuously
flooded fields, which results in emissions of CH4. Anaerobic conditions in these waterlogged
soils lead to the decomposition of organic matter by CH4-emitting bacteria. This CH4 reaches the
atmosphere by bubbling up through the soil, diffusing through water to the surface, or diffusing
through the vascular elements of plants. In some rice-growing states, the climate allows for two
rice crops per season, the second of which is called a “ratoon crop.” Emissions from primary and
ratoon crops should be estimated separately because emissions are higher from ratoon crops.
Nitrous Oxide From Agricultural Soils – Nitrogen Application. Amendments that add nitrogen
to soils increase the production of N2O (nitrous oxide) because they provide additional nitrogen to
the natural cycle of nitrification and denitrification in soils. During nitrification and
denitrification, soil microbes release N2O, which eventually reaches the atmosphere. Commercial
fertilizer, livestock manure, sewage sludge, incorporation of crop residues, and cultivation of
nitrogen-fixing crops—all add nitrogen to soils, a portion of which is released to the atmosphere.
Nitrous Oxide From Agricultural Soils – Organic Soils. Cultivating highly organic soils also
enhances mineralization of nitrogen-rich organic matter, making more nitrogen available for
nitrification and denitrification, which, as described for the previous source, is converted by soil
microbes to N2O and released to the atmosphere.
Lime Application. Lime, in the form of limestone or dolomite, is often added to agricultural soils
to reduce acidic conditions. Lime contains carbonate compounds that, when added to soils,
release CO2.
Cultivation of Organic Soils. Organic soils are soils that, when saturated with water, have 174
grams or more of organic carbon per kilogram of soil if the mineral fraction has 500 grams per
kilogram or more of clay, or 116 grams per kilogram organic carbon if the mineral fraction has no
clay, or has proportional intermediate contents. Agricultural practices—including clearing,
drainage, tillage, planting, grazing, crop residue management, fertilization, and flooding—can
July 29, 2010
Voluntary Reporting of Greenhouse Gases
35
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
alter organic matter inputs and decomposition. In general, more physically disruptive practices
cause a loss of carbon from organic soils, and practices such no-till, conserve the carbon in
organic soils.
Other Agricultural Sources. Enter emissions from any source not listed above. Identify the
source in space provided in column 1 and specify the gas in column 2.
Subtotal. Using the Global Warming Potential (GWP) values found in Appendix E, convert your
Base Period emissions and Reporting Year emissions into units of carbon dioxide equivalent
(CO2e). Sum those CO2e values for each column 5 through 10 and place the totals at the bottom
of each column in the Subtotal row. It is not necessary to include an estimation method or rating
in this row.
e. Fugitive Emissions Associated With Geologic Reservoirs. In Question 1e, enter the amount of
carbon dioxide extracted from natural and man-made geologic reservoirs and fugitive emissions
lost to the atmosphere during the extraction, processing, transport, and injection of carbon dioxide
into geologic reservoirs. Include in your reported emissions any trace quantities of nitrous oxide
and methane. To avoid double-counting, emissions reported in Questions 1a through 1d of
Schedule I, Section 2, Part B, such as fugitive emissions during capture from an industrial or
power plant, should be excluded from this section. In the case of enhanced resource recovery,
particularly enhanced oil recovery (EOR), naturally occurring carbon dioxide is more commonly
used, but a few projects to date use carbon dioxide captured from industrial processes and natural
gas processing. CO2 recaptured and reinjected in enhanced oil recovery (EOR) and enhanced
resource recovery (ERR) cannot be reported.
For more information on emissions and inventory methods associated with geologic
sequestration, see Chapter 1, Part G of the Technical Guidelines.
Follow the General Instructions in Schedule I, Section 2, Part B of this document to fill out the
information requested in each column for each of the following sources:
Fugitive Emissions From the Extraction of Naturally Occurring CO2. Some CO2 will be lost
during the extraction from natural reservoirs. This should be reported as a fugitive emission.
Reporters could use existing monitoring techniques, such as flow meters, to measure the amount
of carbon dioxide lost from the natural geologic reservoirs, or calculate the fugitive emissions
from the natural reservoir using a mass balance method.
Fugitive Emissions During the Extraction of CO2 From Anthropogenic Sources. Include in this
category any fugitive emissions that occur during the extraction of CO2 from anthropogenic
sources, provided these emissions have not already been reported in Schedule I, Section 2, Part B,
Question 1c, Sector-Specific Industrial Process Emissions.
Fugitive Emissions During Transport and Processing. Include in this category any emissions
resulting in the transportation and processing of carbon dioxide from the source to the injection
site, provided these emissions have not already been reported elsewhere in Schedule I, Section 2,
Part B, Question 1.
Fugitive Emissions of CO2 During Injection and Extraction for Enhanced Resource Recovery.
Many enhanced resource recovery operations recycle carbon dioxide used in the recovery process
by re-injecting it into the same well or transferring the carbon dioxide to a new recovery site.
Some carbon dioxide might be lost to the atmosphere during this process of recycling; it may be
July 29, 2010
Voluntary Reporting of Greenhouse Gases
36
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
emitted when injected, and when extracted. Reporters should determine this volume of gas
emitted using flow meters or a mass balance approach.
Post-Injection Seepage of Carbon Dioxide to the Atmosphere.
Evidence has shown that physical leakage rates of carbon dioxide are very small or nonexistent
for carefully selected geologic formations. However, there remains the possibility of future
seepage and entities are responsible for monitoring and reporting such seepage during the
reporting year that the emissions occur. Methods to do so range from maintaining a detector log
of the emissions via the well bore to detecting the amount of carbon dioxide in the formation by
seismic, electromagnetic, gravitational, and geochemical methods.
f.
Captured CO2 Emissions From Anthropogenic Sources. Use question 1f to document the
quantity of carbon dioxide emissions that have captured for subsequent storage in a geologic
reservoir. These captured emissions must be reported as emissions at the point of generation in
Questions 1a through 1d. The Gas (Column 2) and Unit of Measure (Column 3) have been
completed as CO2 and metric tons, respectively, in the printed version of Form EIA-1605. Enter
the average annual quantity stored during the Base Period in onsite (Column 4) and offsite
(Column 5) reservoirs with the total for the Base Period in Column 6. Likewise, enter the average
annual quantity stored during the Reporting Year in onsite (Column 7) and offsite (Column 8)
reservoirs with the total for the Reporting Year in Column 9. Sum the emissions of all sources for
each column (Column 4-9) and enter the result in the Subtotals row.
2. Enter Indirect Emissions From Purchased Energy. Enter information on energy purchased from
other entities only.
a. Physical Quantities of Energy Purchased. Enter the units (e.g., MWh or MMBtu) used to
measure fuel consumption in Column 2. If this is a Start Year Report, enter the physical quantities
of each energy type purchased in the Base Period in Columns 3 through 6. Calculate the Base
Period Average consumption for each energy product by summing the consumption for Base
Period year 1 through year 4 and dividing by the number of years in the Base Period. Enter the
result in Column 7. If this is a Reporting Year report, enter the physical quantity of each energy
product consumed in the Reporting Year in Column 8. Enter Base Period data in Columns 3
through 6 only if you need to revise these data to correct errors or reflect changes to the entity,
such as acquisitions and divestitures. Identify the System Type/Fuel Used for Generation for each
purchased energy product in Column 9 using the codes in Appendix I.
b. Emissions From Purchased Energy for Emissions Inventory. For each energy product
purchased, calculate and enter the associated Base Period (Columns 5-9) or Reporting Year
(Column 10) emissions of carbon dioxide, methane, and nitrous oxide in the data table provided.
Use the appropriate regional electricity emission factors for emission inventories in Appendix F
to estimate indirect emissions from purchases of electricity. Sum the emissions for all purchased
energy sources for the Base Period (Columns 5-9) or Reporting Year (Column 10) in metric tons
CO2e and enter the result in the Totals row.
c. Emissions From Purchased Energy for Emission Reductions. For the purposes of calculating
emission reductions due to reductions for purchased energy, emissions for electricity must also be
calculated using the appropriate regional electricity emission factors for emission reductions in
Appendix F. Only complete this question if you are calculating reductions at the entity level using
Addendum B1 or B2. In the first row of Question 2c, calculate emissions from purchased
electricity in metric tons CO2e for the Base Period (Columns 4-8) or Reporting Year (Column 9),
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
based on the purchased electricity entered in Question 2a and the appropriate regional electricity
emission factors for emission reductions in Appendix F. In the second row enter emissions from
purchased steam, chilled water and hot water in metric tons CO2e. Add these two rows together to
derive values for the Totals (third) row. Note that these values will only be used for calculation of
emission reductions in Addendum B1 or B2 and will not be included in the inventory emissions
for your entity.
3. Enter Other Indirect Emissions. Follow the general instructions for Schedule I, Section 2, Part B to
complete Columns 3 through 9. (Leave Column 10 and 11 blank, since there are no rated methods for
other indirect emissions sources.) Information on the specific sources covered under this category is
provided below.
Entities may choose to report other forms of indirect emissions, such as emissions associated with
employee commuting, manufacture and sale of energy efficient products, consumption of energyintensive products, or indirect nitrous oxide emissions from fertilizer application, although such other
indirect emissions are not to be included in the entity's emission inventory and may not be the basis
for registered emission reductions. All such reports of other forms of indirect emissions must be
distinct from reports of indirect emissions associated with purchased energy and must be based on
emission measurement or estimation methods identified in the Technical Guidelines or approved by
DOE. Methods of estimating indirect emissions are covered in Part F of the Technical Guidelines.
4. Enter Terrestrial Carbon Fluxes and Stocks. Reporters engaged in forestry related activities, crop
cultivation on mineral soils, and pasture/grazing should report the associated carbon sequestration and
emissions here. Special categories of forestry related activities—harvested wood products, land
restoration and forest preservation, natural disturbances, sustainably managed forests, and incidental
lands—are each covered separately.
a. Forestry Activities
The following instructions apply to all the forestry categories under Schedule I, Section 2, Part B,
Question 4a:
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Specific Source/Area Name (Column 2). You may aggregate carbon stocks by the category
listed in Column 1 provided you use the same estimation method for each category. However,
if you prefer to report emissions disaggregated by specific source or area, you may do so
provided you enter a unique name for the source or area in Column 2.
Gas (Column 3). Since carbon stocks and flux must be recorded in units of carbon dioxide,
CO2 is pre-entered in Column 3 on Form EIA-1605.
Units (Column 4). Enter the unit of measure used to quantify the carbon stocks or fluxes
(i.e., metric tons). Note that carbon stocks must be reported in units of carbon dioxide.
Base Period Carbon Stocks (Column 5). Report the Base Period carbon stocks. Base Period
carbon stocks can be an average for a multiple year Base Period or the carbon stocks
estimated for a single year, which can be either the last year in a multiple year Base Period or
the lone year in a single year Base Period.
Estimated Carbon Stocks in Year Prior to Reporting Year (Column 6). Report the
estimated carbon stock of the year prior to the Reporting Year. (Do not complete for a Start
Year report.)
Reporting Year Carbon Stocks (Column 7). Report the estimated carbon stock of the
Reporting Year. (Do not complete for a Start Year report.)
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
•
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Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Reporting Year Stock Change or Carbon Flux (Column 8). Subtract Column 6 from
Column 7 and enter the value here. Reporters using flux-based measurement approaches can
enter the resulting values directly here and leave Columns 6 and 7 blank. Enter the sum of all
rows in the Total row. (Do not complete for a Start Year report.)
Estimation Method (Column 9). Follow the general instructions for Schedule I, Section 2,
Part B, Column 11.
Rating (Column 10). Follow the general instructions for Schedule I, Section 2, Part B,
Column 12.
The following is a description of each source/sink:
Afforestation, Mine Land Reclamation, and Forest Restoration. Afforestation is a change in
land use that may greatly alter the carbon storage on a site. Tree planting activities have the
benefit of producing large gains in carbon storage (at least in the initial decades of tree growth)
because they usually replace land uses that have a relatively constant stock of carbon from year to
year.
Mine land reclamation is a special case of afforestation. Mine land soils are depleted of carbon,
and therefore afforestation on these soils has a greater potential to sequester carbon than any other
forestry activity.
Forest restoration can often be considered a special case of afforestation with regards to
estimating net annual carbon flow. The goal of the restoration activity is to return the land to its
original structure and species composition. If the land is in non-forest use prior to initiation of the
restoration activity, the activity meets the definition of afforestation.
Agroforestry. Agroforestry combines agriculture and silviculture on the same tract of land.
Because it emphasizes the use of woody and perennial crops and biological fertilizers, it may
provide agricultural products with less intensive energy uses and sequester more carbon than
traditional agriculture. Agroforestry activities are made up of a wide range of interdependent
actions. In the face of the difficulties with estimating individual agroforestry activity effects, a
more credible report may result if the analysis is limited to the most certain of the effects, such as
carbon capture and release by trees and soils.
Forest Management. It may be possible to modify the management regimes of existing forests to
increase their rates of carbon capture. Activities may be applied either during the period of forest
growth (intermediate forest treatments) or at the time of harvest and regeneration. These activities
can be divided into intermediate treatments and site preparation techniques.
Intermediate treatments include, but are not limited to, the following:
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Species composition control;
Precommercial thin;
Commercial thin;
Firewood harvests;
Fertilization; and
Prescribed fire.
Site preparation techniques include the following:
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
•
•
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Site preparation burning;
Mechanical site preparation;
Chemical site preparation.
Note that changes in carbon stocks or fluxes from the harvesting of timber itself are reported
separately.
Short-Rotation Biomass Energy Plantations. With woody biomass crops, harvesting occurs
approximately every 5 to 12 years, and regeneration is often accomplished by coppice methods
that rely on regrowth of new stands from the root stock of the harvested stand. The principal
effect of a biomass energy plantation is to displace fossil energy with biomass energy, thereby
reducing fossil-fuel carbon emissions to the atmosphere.
Urban Forestry. Urban forestry activities can have two principal effects on greenhouse gas
emissions and carbon capture. One is carbon capture through tree growth. As with all forestation
activities, urban trees also capture and store carbon in above- and below-ground components, and
may also contribute to carbon uptake in soils. Urban trees also help in energy conservation of
buildings.
Timber Harvesting. Harvesting forests for timber involves a loss of carbon from the disturbance
of the forest soil and the associated felling, and subsequent decay, of non-commercial trees and
branches of trees. The cutting down of trees also ends their ability to sequester carbon in the
future. The carbon sequestered in the harvested wood is released over time depending on how it is
used and is reported separately under wood products.
Other. This category encompasses all other forestry activities landowners may practice with
consequences on carbon storage not otherwise accounted for above.
b. Wood Products. Reporters are provided with two options for reporting on the carbon stock in
harvested wood products. (Do not complete for a Start Year report.)
i.
Method 1. Track and report on emissions from the gradual decomposition of the harvested
wood products on a yearly basis. The following instructions apply to Method 1:
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Units (Column 3). Enter the unit of measure used to quantify the carbon stocks or fluxes
(i.e., metric tons). Note that carbon stocks or flux must be reported in units of carbon dioxide.
Estimated Carbon Stocks in Harvested Wood Products in Year Prior to Reporting Year
(Column 4). Report the estimated carbon stock in harvested wood products in the year prior
to the Reporting Year. For the first year of harvesting, this will be zero.
Estimated Carbon Stocks in Harvested Wood Products in Reporting Year (Column 5).
Report the estimated carbon stock in harvested wood products in the Reporting Year.
Reporting Year Stock Change (Column 6). Subtract Column 4 from Column 5 and enter
the value here.
Estimation Method (Column 7). Follow the general instructions for Schedule I, Section 2,
Part B, Column 10.
Rating (Column 8). Follow the general instructions for Schedule I, Section 2, Part B,
Column 11.
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Method 2. Estimate the carbon remaining in the harvested wood products after 100 years, and
report in the year of harvesting. The following instructions apply to Method 2:
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U.S. Department of Energy
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Form EIA-1605
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Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Units (Column 3). Enter the unit of measure used to quantify the carbon stocks or fluxes
(i.e., metric tons).
Stock of Carbon in Harvested Wood (Column 4). Report the estimated carbon stock in the
harvested wood in the year of harvest.
100-YearResidual Carbon Stock (Column 5). Report the estimated carbon stock remaining
in the harvested wood one hundred years after the year of harvest.
Estimation Method (Column 6). Follow the general instructions for Schedule I, Section 2,
Part B, Column 10.
Rating (Column 7). Follow the general instructions for Schedule I, Section 2, Part B,
Column 11.
c. Land Restoration and Forest Preservation. Entities may restore native habitat on land and
place administrative restrictions to avoid future human-caused releases of carbon. Administrative
restrictions can be permanent conservation easements registered with the County, State, or other
Government entity, or deed restrictions. Check the box if you are certifying that your entity has
placed administrative restrictions on the restored land. Use the instructions below to complete
each row in the table. (Do not complete for a Start Year report.)
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Name/Description of Tract of Land (Column 1). Enter the name or description of the tract
of land.
Type of Restriction (e.g., Easement, Deed Restrictions, etc.), (Column 2). Enter the type
of restriction on the tract of land.
Year Protected (Column 3). Enter the year in which the restriction was applied.
Area (Column 4). Enter the area of the tract of land in acres.
Units (Column 5). Enter the unit of measure used to quantify the carbon stocks or fluxes
(i.e., metric tons). Note that accumulated carbon stocks must be reported in units of carbon
dioxide.
50% of Carbon Stock Accumulated in 50 Years From Inception of Preservation Activity
(Column 6). Enter 50 percent of the carbon stock increases that are expected over the 50
years following the inception of the land restoration and forest preservation activity. Enter the
sum of all rows in the Total row.
Estimation Method (Column 7). Follow the general instructions for Schedule I, Section 2,
Part B, Column 11.
Rating (Column 8). Follow the general instructions for Schedule I, Section 2, Part B,
Column 12.
d. Forest Land That Experiences Carbon Losses From Natural Disturbances. Natural
disturbances beyond the control of landowners can cause great fluxes of carbon, either as
emissions following the disturbance, drastic decreases in carbon stocks, or great absorption of
carbon (in some cases) with regrowth. In order to maintain the credibility of carbon reporting it is
important that such natural disturbances are reported. Should forestland of an entity or subentity
experience a natural disturbance such as a fire or windthrow, the carbon stocks in the disturbance
year (the year in which the disturbance occurs) and for the preceding years should be entered.
Also provide the acreage affected. Entities must track carbon stock changes on each tract of
disturbed lands until carbon stocks reach pre-disturbance levels. Use the instructions below to
complete each row in the table. (Do not complete for a Start Year report.)
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U.S. Department of Energy
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Form EIA-1605
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Voluntary Reporting of Greenhouse Gases
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Name/Description of Tract of Land (Column 1). Enter the name or description of the tract
of land.
Acres (Column 2). Enter the area of the tract of land in acres.
Type of Disturbance (Column 3). Enter the type of disturbance the land experienced.
Year (Column 4). Enter the year in which the disturbance occurred.
Units (Column 5). Enter the unit of measure used to quantify the carbon stocks or fluxes
(e.g., metric tons). Note that carbon stocks and losses must be reported in units of carbon
dioxide.
Base Period (Column 6). Report the Base Period carbon stocks. Base Period carbon stocks
can be an average for a multiple year Base Period or the carbon stocks estimated for a single
year, which can be either the last year in a multiple year Base Period or the lone year in a
single year Base Period.
Carbon Stocks in Year Before Disturbance (Column 7). Report the estimated carbon stock
of the year prior to the disturbance. Enter the sum of all rows in the Total row.
Reporting Year Carbon Stocks (Column 8). Report the estimated carbon stock of the
Reporting Year. Enter the sum of all rows in the Total row.
Loss (Column 9). Subtract Column 8 from Column 7 and enter the value here. Enter the sum
of all rows in the Total row.
Estimation Method (Column 10). Follow the general instructions for Schedule I, Section 2,
Part B, Column 11.
Rating (Column 11). Follow the general instructions for Schedule I, Section 2, Part B,
Column 12.
e. Sustainably Managed Forests. Sustainably managed forests are forests managed to follow
several specific criteria relating to replenishment of harvested trees, low impact logging, and
other related activities. There are various entities that reporters may use to certify that their forests
are sustainably managed. Entities or subentities that sustainably manage forests can report a zero
flux, as it is assumed that the stock of carbon removed through timber harvesting is replaced by
regrowth facilitated by sustainable management practices. There are various third-party
certification systems (e.g., “Sustainable Forestry Initiative (SFI)” and the “Forest Stewardship
Council (FSC)”). Those reporters that have obtained such certification should report it. Use the
instructions below complete each row in the table:
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f.
Name/Description of Tract of Land (Column 1). Enter the name or description of the tract
of land.
Area (Column 2). Enter the area of the tract of land in acres.
Has Sustainability Been Verified by Third Party Certifier (Y/N), (Column 3). Answer
yes or no.
Identify System Used to Determine Sustainability (Column 4). Enter the name of the
certification system used to determine sustainability.
Incidental Lands Excluded from Terrestrial Carbon Fluxes and Stocks in Question 4a.
Entity landholdings that are a minor component of an entity’s operations and are not actively
managed for production of goods and services are considered incidental lands. Reporters can
either use methods specified in the Technical Guidelines to estimate changes in stocks, in which
case this should be reported in Schedule I, Section 2, Part B, Question 4a, or report zero change in
flux. If reporting zero change in flux, please provide information on the acreage and type of
incidental land. If these lands are developed in the future for production of goods and services,
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
the nature of the land-use change must be reported in the next inventory. Use the instructions
below to complete each row in the table:
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Name/Description of Tract of Land (Column 1). Enter the name or description of the tract
of land.
Type of Land (Column 2). Enter a description of the type of land, such as “right-of-way” or
“land around pipeline.”
Area (Column 3). Enter the area of the tract of land in acres. Enter the sum of all rows in the
Total row.
g. Other Terrestrial Carbon Fluxes.
The following instructions apply to all other terrestrial carbon fluxes:
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Specific Source/Area Name (Column 2). You may aggregate carbon stocks by the category
listed in Column 1 provided you use the same estimation method for each category. However,
if you prefer to report emissions disaggregated by specific source or area, you may do so
provided you enter a unique name for the source or area in Column 2.
Units (Column 4). Enter the unit of measure used to quantify the carbon stocks or fluxes
(e.g., metric tons). Note that carbon stocks must be reported in units of carbon dioxide.
Base Period Carbon Stocks (Column 5). Report the Base Period carbon stocks. Base Period
carbon stocks can be an average for a multiple year Base Period or the carbon stocks
estimated for a single year, which can be either the last year in a multiple year Base Period or
the lone year in a single year Base Period.
Estimated Carbon Stocks in Year Prior to Reporting Year (Column 6). Report the
estimated carbon stock of the year prior to the Reporting Year. (Do not complete for a Start
Year report.)
Estimated Carbon Stocks in Reporting Year (Column 7). Report the estimated carbon
stock of the Reporting Year. (Do not complete for a Start Year report.)
Reporting Year Stock Change or Carbon Flux (Column 8). Subtract Column 6 from
Column 7 and enter the value here. Reporters using flux-based measurement approaches can
enter the resulting values directly here and leave Columns 5 and 6 blank. Enter the sum of all
rows in the Total row. (Do not complete for a Start Year report.)
Estimation Method (Column 9). Follow the general instructions for Schedule I, Section 2,
Part B, Column 11.
Rating (Column 10). Follow the general instructions for Schedule I, Section 2, Part B,
Column 12.
The following is a description of each source/sink:
Crops on Mineral Soils. In contrast to organic soils, crop cultivation on mineral soils can actually
lead to greater absorption of carbon. These soils increase their organic matter levels as a result of
increasing crop productivity (providing more residues), less intensive tillage, and other changes in
agricultural management practices. Changes in land-use or management practices that result in
increased organic inputs or decreased oxidation of organic matter (e.g., improved crop rotations,
cover crops, and application of manure) will result in a net accumulation of soil organic carbon
until a new equilibrium is achieved.
Pasture/Grazing. The management of pastures and grazing lands can affect the net flows of
carbon between the soil and the atmosphere. Generally speaking, these lands can be significant
July 29, 2010
Voluntary Reporting of Greenhouse Gases
43
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
sinks for carbon as the soils remain relatively undisturbed. The degree of sequestration depends
upon several factors such as the management regime, quality of pasture, grazing frequency and
intensity.
Land-Use Change. Land-use change is defined for reporting purposes as a change in land
classification between forest land and the following categories: cropland, grassland, and
developed land (including urban land). Land-use change may affect all or part of the land area of
an entity or activity. Since the estimation methods for land-use change may be different than the
estimation methods for other land, determining the area of land-use change is important.
Other. This category encompasses all other forestry activities landowners may practice with
consequences on carbon storage not otherwise accounted for above.
h. Terrestrial Carbon Flux Summary. Enter the requested data from the previous Schedule I,
Section 2, Part B, Question 4a through 4g. (Do not complete for a Start Year report.)
•
•
•
Units (Column 3). Enter the unit of measure used to quantify the carbon stocks or fluxes
(e.g., metric tons). Note that carbon stocks or fluxes must be reported in units of carbon
dioxide.
Reporting Year Stock Change or Carbon Flux (Column 4).
• Forestry Activities. Enter value from Total row of Column 7 of question 4a.
• Wood Products Method 1. Enter value from Column 6 of question 4b.i.
• Wood Products Method 2. Enter value from Column 5 of question 4b.ii.
• Land Restoration and Forest Preservation. Enter value from Total row of Column 6 of
question 4c.
• Sustainably Managed Forests. Leave this row blank.
• Incidental Lands. Leave this row blank.
• Other Terrestrial Carbon Fluxes. Enter value from Total row of Column 7 of question 4g.
Rating (Column 5). Follow the general instructions for Schedule I, Section 2, Part B,
Column 11.
5. Identify and Estimate De Minimis Emissions Sources. List the de minimis sources that you intend
to exclude from your entity-wide emissions inventory, providing the following information about
each source:
• De Minimis Emission Type (Column 1). Enter the emission type (Direct, Indirect, or Carbon
Flux) excluded.
• De Minimis Emission Source (Column 2). Enter the source of the emissions using the codes
listed in Appendix J.
• Gas (Column 3). Enter the type of gas emitted by the source.
• Unit of Measure (Column 4). Enter the unit of measure used to quantify the source.
• Base Period Average De Minimis Emissions (Column 5). Enter the average annual quantity of
the gas emitted during the Base Period.
• Reporting Year De Minimis Emissions (Column 6). Enter the quantity of the gas emitted
during the Reporting Year if emissions from the source were re-estimated.
• Year Last Estimated (Column 7). Enter the year emissions from the source were last estimated.
Enter the last year of your entity’s Base Period if this is a Start Year report or if you have not reestimated emissions since the Start Year. Emissions from de minimis sources must be reestimated after any significant increase in such emissions, or every five years, whichever occurs
sooner.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
44
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Calculate the total Base Period Average and Reporting Year (if applicable) de minimis emission in
metric tons CO2e and enter the result in the last row of Column 5 and 6, respectively.
Part C. Inventory of Foreign Emissions and Carbon Flux
Complete and attach one copy of Addendum A, Inventory of Foreign, Subentity, or Offset Emissions, if
applicable. Part C is optional for independently verified reports. Also complete and attach Addendum C,
Country-Specific Factors from Foreign Sources. When completing Part C, respondents should follow the
same instructions as outlined above for Parts A and B, where applicable.
Part D. Total Emissions and Carbon Flux
Use Part D to summarize the emissions and carbon flux included in your entity’s emissions inventory.
1. Enter Total Domestic Emissions and Carbon Flux. Enter all emissions and flux data in metric tons
of carbon dioxide equivalents (mtCO2e). If this is a Start Year report, enter total Base Period
emissions for each emissions source in Column 3 through 7. If this is a Reporting Year report, enter
total Reporting Year emissions for each emissions or carbon flux source in Column 8. If your entity
has undergone boundary changes due to acquisitions or divestitures since the original Base Period,
update the Base Period emissions data to reflect these changes.
a. Direct Emissions (Item A). Calculate the total direct emissions by summing the total Base
Period emissions (Columns 3-7) or Reporting Year emissions (Column 8) reported for stationary
combustion, mobile sources, sector-specific industrial process emissions, agricultural sources,
and fugitive emissions associated with geologic reservoirs from Part B, Questions 1a through 1e.
Enter the result(s) under Item A in Part D. Biogenic carbon dioxide emissions should not be
included in the total direct emissions.
b. Indirect Emissions From Purchased Energy for Emissions Inventory (Item B). Enter the total
indirect emissions from purchased energy for the emissions inventory for the Base Period
(Columns 3-7) or Reporting Year (Column 8) from Part B, Question 2b. Be sure not to use
indirect emissions from purchased energy for emission reductions (Question 2c), which is to be
used for emission reduction calculations only.
c. Indirect Emissions From Purchased Energy for Calculation of Emission Reductions (Item
C). Enter the total indirect emissions from purchased energy for calculating emission reductions
for the Base Period (Columns 3-7) or Reporting Year (Column 8) from Part B, Question 2c.
d. Total Emissions (Item D). Sum the direct emissions (Item A) and indirect emissions from
purchased energy for emissions inventories (Item B) for the Base Period (Columns 3-7) or
Reporting Year (Column 8). Exclude indirect emissions from purchased energy for calculation of
emission reductions (Item C) from this total. Enter the result(s) under Item D in Part D.
e. Carbon Flux (Item E). Enter under Item E in Part D the carbon flux for the Reporting Year
(Column 8) from Part B, Question 4h, Column 4.
f.
Captured CO2 Sequestered in an Onsite Geologic Reservoir (Item F). Enter under Item F in
Part D the quantities of CO2 sequestered in an onsite geologic reservoir for the Base Period
July 29, 2010
Voluntary Reporting of Greenhouse Gases
45
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
average (Column 7) or Reporting Year (Column 8) as recorded in Part B, Question 1f, Columns 4
and 7, respectively.
g. Total Inventory Emissions (Item G). Calculate total inventory emissions for the Base Period
(Columns 3-7) or the Reporting Year (Column 8) by subtracting carbon flux (Item E) and
captured CO2 sequestered in an onsite geologic reservoir (Item F) from total emissions (Item D).
Enter the result(s) under Item G.
h. Other Indirect Emissions (Item H). Enter under Item H the total other indirect emissions for the
Base Period (Columns 3-7) or Reporting Year (Column 8) from Part B, Question 3.
i.
Captured CO2 Transferred to Another Entity for Sequestration in a Geologic Reservoir
(Item I). Enter under Item I in Part D the quantities of captured CO2 transferred to another entity
for sequestration in a geologic reservoir for the Base Period average (Columns 7) or Reporting
Year (Column 8) as recorded in Part B, Question 1f, Columns 5 and 8, respectively.
2. Enter Total Foreign Emissions and Carbon Flux. Use the instructions for Question 1 above to
enter total foreign emissions and carbon flux. You will need to pull data from the corresponding
questions in Addendum A, Inventory of Foreign, Subentity, or Offset Emissions, as attached to Part
C.
Part E. Emissions Inventory Rating Summary
All entities must complete Part E except those that certify their use of only A- or B-rated estimation
methods to estimate emissions. Large emitters intending to register reductions need to complete this
section for the entire entity. (You need not calculate a separate rating for each subentity included in your
report.) Small emitters intending to register reductions must complete this Part for those activities
included in their inventory, unless they have used only A- or B-rated estimation methods. A weighted
average rating of 3.0 or higher is required to register emission reductions.
Large or small emitters reporting but not registering reductions must complete Part E for the emissions
inventory they submit, whether this inventory is entity-wide or covers only those activities for which
reductions are to be reported but not registered. This rating need not achieve an average of 3.0 or higher.
A large or small emitter reporting but not registering reductions may also certify the use of only A- and
B-rated estimation methods and skip Part E.
If this is a Start Year report, you should complete Question 1 only.
If this is a Reporting Year report, you should:
• complete Question 2; and
• complete Question 1 if you have submitted revised Base Period emissions data in Part B.
•
Enter Base Period Data.
Follow the steps below to calculate the weighted average emissions inventory rating for the Base Period
in Part E, Question 1. Calculate and enter data for domestic and foreign emissions sources separately.
•
For each rating category (A, B, C, and D), enter the total Base Period average domestic and
foreign direct emissions calculated using methods with the corresponding rating in the
July 29, 2010
Voluntary Reporting of Greenhouse Gases
46
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
appropriate row under the direct emissions column (Column 3). Likewise, enter total domestic
and foreign indirect emissions from purchased energy (Column 4).
•
•
For each rating category, sum the total of direct emissions (Column 3) and indirect emissions
from purchased energy (Column 4), and enter in the total emissions column (Column 6). Sum the
values for each rating category and enter the result in the Totals row for this column.
•
For each rating category, multiply the total emissions (Column 6) by the weighting factor
(Column 2) and enter the result in the weighted total emissions column (Column 7). Sum the
values for each rating category and enter the result in the Totals row for this column.
•
Calculate the weighted average emissions inventory rating by dividing the total in Column 7 by
the total in Column 6. Enter this value under the weighted total emissions column (Column 7) in
the Weighted Average Rating row.
Enter Reporting Year Data.
Follow the steps below to calculate the weighted average emissions inventory rating for the Reporting
Year in Part D, Question 2. Calculate and enter data for domestic and foreign emissions sources
separately.
•
For each rating category (A, B, C, and D), enter the total Reporting Year domestic and foreign
direct emissions calculated using methods with the corresponding rating in the appropriate row
under the direct emissions column (Column 3). Likewise, enter total domestic and foreign
emissions or flux by rating category in the respective columns for indirect emissions from
purchased energy (Column 4) and carbon flux (Column 5). Enter carbon flux as a positive value,
regardless of whether the flux was positive or negative.
•
For each rating category, sum the total direct emissions (Column 3), indirect emissions from
purchased energy (Column 4), and carbon flux (Column 5) and enter in the total emissions and
carbon flux column (Column 6). Sum the values for each rating category and enter the result in
the Totals row for this column.
•
For each rating category, multiply the total emissions and carbon flux (Column 6) by the
weighting factor (Column 2) and enter the result in the weighted total emissions and carbon flux
column (Column 7). Sum the values for each rating category (A through D) and enter the result in
the Totals row of Column 7.
•
Calculate the weighted average emissions inventory rating by dividing the weighted total
emissions (Column 7) in the Totals row by total emissions and carbon flux (Column 6) in the
Totals row. Enter this value under the weighted total emissions and carbon flux column (Column
7) in the Weighted Average Rating row.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
47
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Section 3. Emissions Offsets
Complete Section 3 only for Reporting Year reports. Indicate by checking the appropriate check boxes at
the beginning of Section 3 whether you have obtained emission offsets from another reporting entity (or
entities) or from entities that choose not to report under the 1605(b) program (non-reporter). You must
have an agreement with the other entity that permits you to report the offsets.
Part A. Offsets Obtained by Agreement With Other Reporters
Complete Part A if you have obtained emissions offsets by agreement with other reporters to the
Voluntary Reporting of Greenhouse Gases Program. By registering or reporting but not registering
offsets in Part A, you are confirming the existence of an agreement between your entity and the entity
providing the emissions offset to permit the inclusion of the emissions offset in your report.
For each offset obtained, enter the following information in the data table provided:
•
•
•
•
•
•
•
Name of Other Reporter (Column 1). Enter the name of the other reporter in Column 1, using the
name as it appears in the other entity’s Form EIA-1605.
Name of Other Reporter’s Subentity (Column 2). If applicable, enter in Column 2 the name of the
other reporter’s subentity for which the offset was reported as it appears in the other entity’s Form
EIA-1605.
Domestic or Foreign (Column 3). Indicate in Column 3 whether the offset was derived from a
domestic or foreign emissions source.
Gas (Column 4). Enter CO2e unless the offset is for a CFC, in which case enter the code for the
specific CFC from Appendix E.
Unit of Measure (Column 5). Enter metric tons unless the offset is for a CFC, in which case you
may report the quantity in kilograms.
Quantity (Column 6). Enter the quantity of the offset obtained in metric tons CO2e in Column 6,
unless the gas is a CFC, in which case enter the quantity in kilograms or metric tons of the specific
gas.
Registered by Other Reporter? (Column 7) Indicate whether the offset was registered by the
reporter from whom it was obtained by entering “Y” for yes or “N” for no in Column 7.
Part B. Offsets Obtained by Agreement With a Non-reporter
Complete Part B if you have obtained emission offsets from one or more non-reporters to the Voluntary
Reporting of Greenhouse Gases Program. In addition to providing the information below, you must attach
Schedules I, II (if applicable), III , and the form for the appropriate emission reduction method
(Addendum B1-B16) completed by, or on behalf of, the non-reporter.
For each offset obtained, enter the following information in the data table provided:
•
•
•
•
Name of Non-reporter (Column 1). Enter the name of the non-reporter in Column 1.
Domestic or Foreign (Column 2). Indicate in Column 3 whether the offset was derived from a
domestic or foreign emissions source.
Gas (Column 3). Enter CO2e unless the offset is for a CFC, in which case enter the code for the
specific CFC from Appendix E.
Unit of Measure (Column 4). Enter metric tons unless the offset is for a CFC, in which case you
may report the quantity in kilograms.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
48
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
•
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Quantity (Column 5). Enter the quantity of the offset obtained in metric tons CO2e in Column 5,
unless the gas is a CFC, in which case enter to quantity in kilograms or metric tons of the specific gas.
Non-reporter Has Met Requirements for Registration? (Column 6) Indicate whether the nonreporter has met the requirements for registering reductions in the attached report by entering “Y” for
yes or “N” for no in Column 6.
Section 4. Entity-Level Emission Reductions
Do not complete this section if you are estimating reductions for two or more subentities. If you intend to
use more than one emissions reduction method, you must delineate subentities, unless you are registering
reductions estimated at the entity level on Addendum B1 or B5 and would like to supplement your report
with reported but not registered reductions (also estimated at the entity level) on Addendum B2.
If this is a Reporting Year Report, you must select the same method as indicated in your Start Year
Report. Contact the Communications Center if you wish to change your reduction method as established
in the Start Year Report.
1. Indicate the method used to estimate entity-wide emission reductions by checking the appropriate
checkbox. If emission reductions are not being reported for this entity, check the last checkbox listed.
2. If you are registering reductions for this entity estimated using the Changes in Emissions Intensity
(Addendum B1) or Energy Generation and Distribution (Addendum B5) methods, indicate whether or
not you also are reporting but not registering reductions calculated using the Changes in Absolute
Emissions (Addendum B2) method. You may choose to supplement your report of registered
reductions using an intensity-based method with a report of reduction in absolute emissions even if
the output of the entity is declining. The reductions in absolute emissions included in this
supplemental report are not eligible for registration.
3. Complete and attach one copy of the emission reduction addendum (Addendum B1-B16) indicated in
Question 1 that was used to estimate reductions in domestic emissions.
4. If you are reporting non-U.S. emissions within one entity-level report, attach one copy of the
emission reduction addendum (Addendum B1-B16) indicated in Question 1 that was used to estimate
reductions in foreign emissions. If you choose to use a different Base Period or emission reduction
estimation method for foreign emissions, you must create a separate subentity.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
49
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for Schedule II, Subentity Information
Section 1. Subentity Statement
Complete this schedule for each subentity included in your report.
1. Enter Subentity Identification: List the subentity's name, its description, and relationship to the
entity.
2. Enter Reason for Delineation of the Subentity: Check all applicable box(es) to explain the
reason(s) for delineating the subentity.
Distinct estimation method: Check this box if you intend to use different methods to calculate
reductions for your subentities. Indicate which estimation method you plan to use to calculate
reductions for this specific subentity by checking the appropriate box.
Distinct output metric: Check this box if you intend to calculate separate emission reductions
using the changes in emission intensity method for one or more other subentities because a
different metric is required to accurately measure output.
Foreign country operations, specify country(ies): Check this box if the subentity includes
operations in a foreign country. Identify the country or countries included in this specific
subentity by entering the 3-digit country codes in the space provided. (See Appendix C for a list
of country codes.)
Distinct Base Period from other subentities (for new or acquired operations): Check this box if
the subentity has a distinct Base Period from other subentities.
Emission reduction calculation method changed: Check this box if the reduction calculation
method has changed, resulting in a distinct subentity.
Small emitter registering emission reductions associated with more than one specific activity:
Check this box if reductions are being estimated for more than one specific activity conducted by
a small emitter that intends to register emission reductions. If the entity intends to register
reductions for only one specific activity, the required inventory for this activity may be reported
on Schedule I, Section 2.
Reporting but not registering emission reductions associated with more than one specific
activity: Check this box if reductions are being estimated for more than one specific activity
conducted by an entity that intends to report but not register emission reductions. If the entity
intends to register reductions for only one specific activity, the required inventory for this activity
may be reported on Schedule I, Section 2.
Distinct organizational unit or other component of entity: Check this box if the reductions are
being estimated for a distinct organizational unit or other component of the entity, such as a
discrete business line, facility, plant, vehicle fleet, or energy using system.
Not practicable to assess the changes in net emissions for the following reasons: Check this
box if you cannot assess the change in net emissions. Please explain how it is not practicable to
assess the change in the space provided.
3. Enter Significant Changes to Previous the Subentity Statement: Complete this question if this is a
Reporting Year report. If the subentity is not new and has not undergone significant changes since the
previous year’s report, check the first checkbox. Otherwise, check the appropriate boxes describing
the changes your subentity has undergone and provide descriptive information where requested.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
50
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
4. Describe the Subentity’s Primary Economic Activities (NAICS Code): Enter the primary (and, if
applicable, secondary) 3-digit NAICS code for the subentity. (For a list of NAICS codes, see
Appendix A.)
5. Describe the Organizational Boundaries of the Subentity: Please use the space provided to
describe the organizational boundaries of this specific subentity.
6. Describe the Scope of the Emissions Inventory for the Subentity: If there are emissions associated
with this subentity, check the applicable box for each of the emissions sources included in the
emissions inventory for this specific subentity reported in Addendum A.
7. Describe the Geographic Scope of Activities of the Subentity: Please check the appropriate box to
indicate whether this report covers U.S. activities or non-U.S. activities. If you checked “This report
covers U.S. activities only,” check the box indicating the scope of the subentity’s activities in the U.S.
using the following criteria:
Nationwide: Check the box for nationwide if your subentity has operations in at least one state in
each of the 9 U.S. Census Divisions. The U.S. Census Divisions are identified in Appendix B.
Multiple States: Check the box for multiple States if your subentity has operations in more than
one State but does not meet the criteria for nationwide. List the States in which your subentity has
operations using the two-letter abbreviations listed in Appendix B.
Single State: Check the box for single State if your subentity has operations in only one State.
Identify the state in the space provided using two-letter abbreviations listed in Appendix B.
If you checked the box indicating that this subentity report covers non-U.S. activities, identify the
foreign country or countries in which reported activities occurred using the 3-digit country codes
found in Appendix C.
8. Indicate the Inclusion of Emission Reductions: Check “Yes” or “No” to indicate whether emission
reductions are included in this year's report for this specific subentity. If “No,” explain why.
9. Define the Subentity Base Period: Check the box indicating the number of years in the Base Period
for the subentity, and enter the last (most recent) year of the Base Period.
10. Enter Any Supplementary Information for Subentity: Use this space to provide any supporting
information about this subentity that you feel should be included in your report. Attach additional
sheets if necessary.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
51
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Section 2. Subentity Emissions Inventory
For each subentity included in your report, complete and attach one copy of Addendum A, Inventory of
Foreign, Subentity, or Offset Emissions.
If you are a large emitter intending to register reductions, the subentities you establish for the purpose of
calculating reductions must, when aggregated, include all the emission sources and carbon sinks in your
entity. The sum of emissions and carbon flux reported for these subentities in Schedule II must equal the
total entity-level emissions reported in Schedule I, Section 2, Part D.
If you are a small emitter or a large emitter intending to report but not register reductions, you may
establish one or more subentities that include the emissions sources associated with the activity for which
you are estimating reductions. The inventory prepared for each subentity must represent a complete
assessment of the emissions and sequestration associated with the specific activity covered by the
subentity.
Section 3. Subentity Emission Reductions
If this is a Reporting Year Report, you must select the same method as indicated in your Start Year
Report. Contact the Communications Center if you wish to change your reduction method as established
in the Start Year Report.
1. Indicate the method used to estimate emission reductions for this subentity by checking the
appropriate checkbox.
2. If you are registering reductions for this subentity estimated using the Changes in Emissions Intensity
(Addendum B1) or Energy Generation and Distribution (Addendum B5) methods, indicate whether or
not you also are reporting but not registering reductions calculated using the Changes in Absolute
Emissions (Addendum B2) method. You may choose to supplement your report of registered
reductions using an intensity-based method with a report of reduction in absolute emissions even if
the output of the subentity is declining. The reductions in absolute emissions included in this
supplemental report are not eligible for registration.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
52
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Instructions for Schedule III, Emission Reductions
Section 1. Registered Emission Reductions
Use Schedule III, Section 1 to summarize the registered emission reductions entered in Schedule I or
Schedule II and their associated emission reduction addenda. Enter domestic registered emission
reductions in Part A and foreign registered emission reductions in Part B. Table 1 below indicates the
source in Addendum B for each data value in the corresponding cells in the data tables for Parts A and B.
Abbreviated references are used to conserve space, which are explained via example below:
•
•
B1, H2 refers to the value in Addendum B1, Item H, Column 2.
B1, Part C.1 refers to data in Addendum B1, Part C, Question 1.
If you are registering reductions for your entire entity, and you have not reported on subentities, complete
both Parts A and B using the same data from Addendum B and Schedule I referenced in Table 1.
If you are registering reduction based on subentities, complete both parts A and B using the summation of
all Addenda submitted to Schedule II referenced in Table 1 below.
Use the following instructions for completing the following Items in Parts A and B:
•
•
•
•
•
•
•
Column 2. Enter total gross registered reductions by emission method/source (or Addendum
type).
Column 3. Enter any registered reductions distributed to others by emission method/source
(or Addendum type).
Column 4. Subtract Column 3 from Column 2 for all items.
Item P. Sum the values in Columns 2 and 3 for Items A1 through O to get all reductions from
Addendum B1-B15 and enter the result in the respective column under Item P.
Item R. Sum the values in Column 2 and 3 for Items P through Q2 to get total reductions
plus offsets and enter the result in the respective column under Item R.
Item S. Enter reduction deficits carried over from last year’s report in Column 4. For
domestic reductions (Part A), enter value from Schedule III, Section 1, Part A, Item T in your
previous year’s report. For foreign reductions (Part B), enter value from Schedule III, Section
1, Part B, Item T in your previous year’s report. For both domestic and foreign, if the value is
negative, enter the value, and, if it is zero or positive, enter zero.
Item T. In Column 4, add Item R and Item S and enter total net registered reductions.
Table 1. Net Entity-Level Registered Reductions and Carbon Storage (metric tons CO2e)
1
2
3
4
Emission Reductions
Item
A
Method/Source
Gross
Registered
Reductions
Registered
Reductions
Distributed to
Other
Reporters
Net
Registered
Reductions
(Subtract
Column 3 from
Column 2)
Changes in Emissions Intensity
B1, I2
A1
Direct
A2
Indirect From Purchased Energy
July 29, 2010
B1, I3
Voluntary Reporting of Greenhouse Gases
B1, Part C.1
(Column 5)
B1, Part C.1
(Column 5)
53
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
1
2
3
4
Emission Reductions
Method/Source
Item
B
Gross
Registered
Reductions
Registered
Reductions
Distributed to
Other
Reporters
Net
Registered
Reductions
(Subtract
Column 3 from
Column 2)
Changes in Absolute Emissions
B2, G2
B1
Direct
B2
Indirect From Purchased Energy
B2, G3
B3, H3
C
Changes in Carbon Storage
D
Changes in Avoided Emissions
E
Energy Generation and Distribution
F
Coal Mine Methane Recovery
G
Landfill Methane Recovery
H
Geologic Sequestration
I
Electricity Transmission and Distribution
Improvements
J
Capture of Methane From Anaerobic Digestion
at Wastewater Treatment Facilities
K
Anaerobic Digestion of Animal Waste
L
Recycling of Fly Ash
M
Demand-Side Management or Other Emission
Reduction Programs
N
Combined Heat and Power
O
Other Action-Specific Methods
B4, H6
B5, K6
B6, CC5
B7, DD6
B8, I3
B9, R3
B10, HH6
B11, E3
B12, J3
B15, M3
O1
Direct
O2
Indirect From Purchased Energy
P
July 29, 2010
B13, Part B.1,
(Column 5 of
Total row)
B14, OO3
B15, M4
B2, Part C.1
(Column 5)
B2, Part C.1
(Column 5)
B3, Part B.1
(Column 4 of
Total row)
B4, Part C.1
(Column 4 of
Total row)
B5, Part C.1
(Column 4 of
Total row)
B6, Part D.1
(Column 4 of
Total row)
B7, Part D.1
(Column 4 of
Total row)
B8, Part D.1
(Column 4 of
Total row)
B9, Part D.1
(Column 4 of
Total row)
B10, Part D.1
(Column 4 of
Total row)
B11, Part D.1
(Column 4 of
Total row)
B12, Part D.1
(Column 4 of
Total row)
B13, Part C.1
(Column 4 of
Total row)
B14, Part C.1
(Column 4 of
Total row)
B15, Part C.1
(Column 5)
B15, Part C.1
(Column 5)
Subtotal (Sum rows A1 through O2)
Voluntary Reporting of Greenhouse Gases
54
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
1
2
3
4
Emission Reductions
Method/Source
Item
Q
Net
Registered
Reductions
(Subtract
Column 3 from
Column 2)
Offsets
Q1
Offsets Obtained From Other Reporters
Q2
Offsets Obtained From Non-reporters
R
S
Gross
Registered
Reductions
Registered
Reductions
Distributed to
Other
Reporters
–Total from
Schedule I,
Section 3, Part
A, Column 6*
–Total from
Schedule I,
Section 3, Part
B, Column 6*
Subtotal (Sum rows P through Q2)
Reduction Deficits Carried Over From Last
Year’s Report
T
TOTAL (Add row R to row S)
*Include total of registered domestic offsets in Part A and total of registered foreign offsets in Part B.
Section 2. Reported but Not Registered Emission Reductions
Use Schedule III, Section 2 to summarize the reported but not registered emission reductions entered in
Schedule I or Schedule II and their associated emission reduction addenda. Enter domestic emission
reductions in Part A and foreign emission reductions in Part B. Table 2 below indicates the sources in
Addendum B for each data value in the corresponding cells in the tables for Parts A and B. Abbreviated
references are used to conserve space, which are explained via example below:
•
•
B1, H2 refers to the value in Item H, Column 2 of Addendum B1.
B1, Part C.1 refers to data in Part C, Question 1 of Addendum B1.
Complete both Parts A and B using the same data from Addendum B and Schedule I referenced in Table
2 below.
Use the following instructions for completing the following items in Parts A and B:
•
•
•
•
July 29, 2010
Column 4. Subtract Column 3 from Column 2 for all items.
Item P. Sum the values in Columns 2 and 3 in Items A1 through O and enter the result in the
respective column under Item P.
Item R. Sum the values in Column 2 and 3 in Items P through Q2 and enter the result in the
respective column under Item R.
Item S. Enter reduction deficits carried over from your previous year’s report in Column 4.
For domestic reductions (Part A), enter value from Schedule III, Section 2, Part A, Item T in
your previous year’s report. For foreign reductions (Part B), enter value from Schedule III,
Section 2, Part B, Item T in your previous year’s report. For both domestic and foreign
reductions, if the value is negative, enter value, and, if it is zero or positive, enter zero.
Voluntary Reporting of Greenhouse Gases
55
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
•
•
•
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Item U. If in Addendum B2 you have checked “Yes” to Part A, Question 4, enter any
emissions reductions both reported but not registered on Addendum B2 and registered on
Addendum B1 in Column 4 only.
Item W. Enter the reduction deficit for the CFC carried over from last year’s report in
Column 4 only. For Domestic, enter value from Schedule III, Section 2, Part A, Item X in
previous year’s report. For Foreign, enter value from Schedule III, Section 2, Part B, Item X
in previous year’s report. For both Domestic and Foreign, if the value is negative, enter value,
and, if it is zero or positive, enter zero.
Item X. Enter the sum of rows V and W in Column 4 only.
Table 2. Net Entity-Level Reported but Not Registered Reductions and Carbon Storage
1
2
3
4
Emission Reductions
Net
Reported
Reported
Reductions
Reductions
Gross
Distributed
(Subtract
Reported
to Other
Column 3 from
Item
Method/Source
Reductions
Reporters
Column 2)
Carbon Dioxide, Methane, Nitrous Oxide, Perfluorocarbons, Hydrofluorocarbons, and Sulfur
Hexafluoride (metric tons CO2e)
A
Changes in Emissions Intensity
B1, I2
A1
Direct
A2
Indirect From Purchased Energy
A3
Other Indirect
B
B1, I3
B1, I4
B1, Part C.1
(Column 5)
B1, Part C.1
(Column 5)
B1, Part C.1
(Column 5)
Changes in Absolute Emissions
B2, H2
B1
Direct
B2
Indirect From Purchased Energy
B3
Other Indirect
B2, H3
B2, H4
B3, H3
C
Changes in Carbon Storage
D
Changes in Avoided Emissions
E
Energy Generation and Distribution
F
Coal Mine Methane Recovery
G
Landfill Methane Recovery
H
Geologic Sequestration
I
Transmission and Distribution Improvements
B4, H6
B5, K6
B6, CC5
B7, DD5
B8, I3
B9, R3
July 29, 2010
Voluntary Reporting of Greenhouse Gases
B2, Part C.1
(Column 5)
B2, Part C.1
(Column 5)
B2, Part C.1
(Column 5)
B3, Part B.1
(Column 4 of
Total row)
B4, Part C.1
(Column 4 of
Total row)
B5, Part C.1
(Column 4 of
Total row)
B6, Part D.1
(Column 4 of
Total row)
B7, Part D.1
(Column 4 of
Total row)
B8, Part D.1
(Column 4 of
Total row)
B9, Part D.1
(Column 4 of
Total row)
56
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
1
2
3
4
Emission Reductions
Net
Reported
Reported
Reductions
Reductions
Gross
Distributed
(Subtract
Reported
to Other
Column 3 from
Method/Source
Item
Reductions
Reporters
Column 2)
Carbon Dioxide, Methane, Nitrous Oxide, Perfluorocarbons, Hydrofluorocarbons, and Sulfur
Hexafluoride (metric tons CO2e)
J
Capture of Methane From Anaerobic Digestion at
Wastewater Treatment Facilities
K
Anaerobic Digestion of Animal Waste
L
Recycling of Fly Ash
M
Demand-Side Management or Other Emission
Reduction Programs
N
Combined Heat and Power
O
Other Action-Specific Methods
B10, HH6
B11, E3
B12, J3
B15, N3
O1
Direct
O2
Indirect From Purchased Energy
O3
Other Indirect
P
Q
B15, Part C.1
(Column 5)
B15, Part C.1
(Column 5)
B15, Part C.1
(Column 5)
Subtotal (Sum rows A1 through O)
Offsets
Offsets Obtained From Other Reporters
Q2
Offsets Obtained From Non-reporters
R
–Total from
Schedule I,
Section 3, Part
A, Column 6*
Total from
Schedule I,
Section 3, Part
B, Column 6*
Subtotal (Sum rows P through Q2)
Reduction Deficits Carried Over From Last Year’s
Report
T
U
B15, N4
B15, N5
Q1
S
B13, Part B.1,
(Column 5 of
Total row)
B14, OO3
B10, Part D.1
(Column 4 of
Total row)
B11, Part D.1
(Column 4 of
Total row)
B12, Part D.1
(Column 4 of
Total row)
B13, Part C.1
(Column 4 of
Total row)
B14, Part C.1
(Column 4 of
Total row)
TOTAL (Add row R to row S)
Emission Reductions Also Registered as Emission
Intensity Reductions
Chlorofluorocarbons (CFCs) and Other Gases (Kilograms of native gas) Attach additional copies of
Part A or B if reporting but not registering reductions in domestic emissions of more than one gas.
V
Destruction of CFCs or Reductions of Other
Gases.
Specify Gas: ___________
July 29, 2010
B16, B.1
(Column 3 of
each row)
Voluntary Reporting of Greenhouse Gases
B16, C.1
(Column 4 of
each row)
57
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
1
2
3
4
Emission Reductions
Net
Reported
Reported
Reductions
Reductions
Gross
Distributed
(Subtract
Reported
to Other
Column 3 from
Method/Source
Item
Reductions
Reporters
Column 2)
Carbon Dioxide, Methane, Nitrous Oxide, Perfluorocarbons, Hydrofluorocarbons, and Sulfur
Hexafluoride (metric tons CO2e)
W
Reduction Deficit for this CFC or Other Gas
Carried Over From Last Year’s Report
X
TOTAL (Add row V to row W)
*Include total of reported domestic offsets in Part A and total of reported foreign offsets in Part B.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
58
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for Schedule IV, Verification and Certification
Section 1. Independent Verification
If your report has been independently verified, you must still provide the certification outlined in section
2, below.
If your report has been independently verified by a qualified verifier in accord with §300.11 of 10 CFR
Part 300, Guidelines for Voluntary Greenhouse Gas Reporting, that verifier must complete Schedule IV,
Section 1. Otherwise, skip to Section 2 of Schedule IV, Reporter Self Certification.
1. Enter the Name of the Entity Whose Report Has Been Independently Verified
Enter the name of the entity report for which you have provided independent verification. This name
should be unique and match the name submitted on Schedule I, Section 1, Question 1.
2. Describe the Identity of Independent Verifier
Provide the legal name and complete address of the verifying company or individual. Provide the name
and contact information of a person employed by the company that can answer questions about the
verification of this Form EIA-1605 submission.
3. Define the Independent Verifier Qualifications
a. Corporate Accreditation(s)
Indicate accreditations held by your company by checking all boxes that apply. If the company is not
accredited by any organization listed but is accredited by another nationally recognized certification
program, check “Other,” and describe the unlisted organization providing accreditation.
b. Independent Verifier Personnel Accreditation(s)
Provide the names of the lead verifier and other personnel on the verification team. For each of the
personnel, provide their title, any relevant degrees, and any professional accreditations (e.g., professional
engineer, certified public accountant) they may hold. Please also indicate whether each listed member of
the verification team meets the requirements of §300.11(b) of 10 CFR Part 300, Guidelines for Voluntary
Greenhouse Gas Reporting. This section requires that all members of the verification team:
1) have education, training, and/or professional experience that matches the tasks they perform;
2) are familiar with the requirements of §300.11(b) of 10 CFR Part 300, Guidelines for Voluntary
Greenhouse Gas Reporting;
3) are familiar with the subject matter covered in the verification;
4) have knowledge of greenhouse gas emission and emission reduction quantification;
5) have knowledge of data and information auditing sampling methods; and
6) are familiar with risk assessment methodologies and materiality analysis procedures outlined by
other domestic and international standards.
In addition to these qualifications, the lead verifier should also:
July 29, 2010
Voluntary Reporting of Greenhouse Gases
59
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
1) be accredited by one or more nationally recognized accreditation programs; and
2) have experience managing an auditing or verification process, including recruitment and
allocation of a verification team.
c. Independent Verification Approach
Indicate the activities included in the independent verification of this report by checking all of the boxes
that apply.
4. Certification of Independent Verification
Indicate the name of the entity for which you have performed an independent verification and the data
period that your verification covered. The form must then be signed and dated by the lead certifier of the
verification team and a corporate officer of your company, if one exists, certifying that each of the listed
eight conditions have been achieved.
Section 2. Reporter Self Certification
As noted in §300.10 of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting, all reports
submitted to EIA on Form EIA-1605 must be certified by the Chief Executive Officer, Agency Head, or
an officer or employee of the entity who is responsible for reporting the entity’s compliance with
environmental regulations. If the report has been submitted on behalf of a household, any adult member
of the household may certify the report.
1. Certification
Provide the name, title and contact information of the person certifying your report. If reporting but not
registering reductions, this person must certify by signing and dating the form that, to the best of the
person’s knowledge and belief, the information submitted on the form meets the first three requirements
listed in this section. If registering reductions, signing and dating the form indicates that the first three
requirements have been met and the subsequently listed five requirements have also been met.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
60
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for Addendum A, Inventory of Foreign,
Subentity, or Offset Emissions
Part A. Aggregated Emissions by Gas (for Independently Verified
Reports Only)
Use the instructions for Schedule I, Section 2, Part A to complete Addendum A, Part A. Note that you
must complete only one summary table for aggregate emissions; enter either entity-wide foreign
emissions, subentity, or offset emissions as appropriate. Only complete the “Weighted Rating” column if
this copy of Addendum A is being completed for entity-wide foreign operations.
Part B. Inventory of Emissions and Carbon Flux
Use the instructions for Schedule I, Section 2, Part B to complete Addendum A, Part B. If you are using
Addendum A to report for a subentity, ignore the instructions for providing rating information. Only
complete the “Weighted Rating” column if this copy of Addendum A is being completed for entity-wide
foreign operations.
Part C. Total Foreign, Subentity, or Offset Emissions and Carbon Flux
Use the instructions for Schedule I, Section 2, Part D to complete Addendum A, Part C.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
61
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for Addendum B, Emission Reduction Methods
B1. Changes in Emissions Intensity
Complete Addendum B1 if you intend to calculate reductions using the emissions intensity approach for
your entity or subentity. If you are reporting reductions for a subentity, enter the name of the subentity in
the space provided.
Part A. Output
1. Enter the Physical, Economic, or Indexed Output Measure for the Base Period and Reporting
Year. Enter information for the specific output measure you have selected under the appropriate
Item(s) for PHYSICAL (Item A), ECONOMIC (Item B and C), or INDEXED measure (Item D).
Enter Base Period output data in Columns 4 through 8 and Reporting Year output in Column 9. Note
that you are to enter data for only one output measure type (PHYSICAL, ECONOMIC, or
INDEXED), completing either Item A, Items B and C, or Item D.
a. If a PHYSICAL measure is selected, enter a brief description under output measure (Item A,
Column 1) and indicate the unit of measure in Item A, Column 2. For example, a cement
manufacturer might enter “quantity of clinker” under output measure and “metric tons” under
unit of measure.
b. If an ECONOMIC measure is selected, enter a brief description under output measure (Items
B and C, Column 1). Provide the output measure in current dollar value(s) under Item B.
Calculate the constant dollar value(s) (in $2000) by multiplying the current value by the GDP
price deflators found in Appendix K and enter under Item C.
c. If an INDEXED measure is selected, enter a brief description of the basis of the INDEXED
measure under output measure (Item D, Column 1). For example, a steel manufacturer could
enter tons of steel or dollar sales of steel. In Item D, Column 2, denote if the index is based on
a physical or economic measure.
d. If reporting Base Period data, enter the value(s) for the PHYSICAL, ECONOMIC, or
INDEXED measure under each of the years in the Base Period columns. If you have a single
year in your Base Period, enter the output value for this year under Year 1 (Column 3). If you
have multiple years in your Base Period, enter the output value for the first year under Year 1
(Column 3), the output value for the second year under Year 2 (Column 4), and so on. See
Section 2.3.1 of the Technical Guidelines for a discussion of selecting the Base Period.
e. If submitting Base Period data, calculate a simple average for the Base Period by summing
the output values reported under Year 1 through Year 4 (Columns 3-6) and dividing this total
by the number of years in the Base Period. Enter the result under average (Column 7). Note
that if using INDEXED output measures, the Base Period average (Item D, Column 7) index
number should be set equal to 100.
f. If submitting Reporting Year data, enter the value for the PHYSICAL, ECONOMIC, or
INDEXED measure under the Reporting Year column.
2. If Providing an Output Measure Not Described in the Technical Guidelines, Indicate Reason
Why Alternative Measure Was Selected. If the output measure you are using is not listed in Tables
2.1 and 2.2 of the Technical Guidelines (also see Appendix L of these instructions), check the box(es)
to indicate why you selected an alternate measure.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
3. Define and Describe the Output Measure Used and Provide a Rationale for Why the Measure
Was Selected. If your output measure is not included in Tables 2.1 and 2.2 of the Technical
Guidelines (also see Appendix L of these instructions), explain briefly why the selected output
measure is a good indicator of changes in emissions.
Part B. Emissions, Emissions Intensity, Emission Reductions
1. Enter Base Period and Reporting Year Emissions. Enter Base Period emissions data under Item E
and Reporting Year data under Item F in metric tons CO2e as recorded in your entity or subentity
emissions inventory (for an entity Schedule I, Section 2, Part D; for a subentity Addendum A, Part C
as attached in Schedule II, Section 2). Enter the total quantity of direct emissions in Column 2 as
entered in Part D, Item A of your entity emissions inventory or Part C, Item A of your subentity
emissions inventory. Be sure direct emissions include any CO2 captured and sequestered in geologic
reservoirs (onsite and offsite). Enter indirect emissions from purchased energy in Column 3 as
recorded in Part D, Item C (indirect emissions from purchased energy for calculation of emission
reductions) of your entity emissions inventory or Part C, Item C of your subentity emissions
inventory. Enter other indirect emissions in Column 4 as recorded in Part D, Item H of your entity
emissions inventory or Part C, Item H of your subentity emissions inventory.
2. Calculate and Enter Base Period and Reporting Year Intensity. Calculate Base Period emissions
intensity for direct emissions, indirect emissions from purchased power, and other indirect emissions
by dividing the appropriate emissions value (for Direct, Indirect Emissions from Purchased Power,
and Other Indirect) under Item E (Part B, Question 1) by the corresponding PHYSICAL,
ECONOMIC, or INDEXED Output Measure recorded under Items A, C, or D (Part A, Question 1).
Enter the result under Item G in Column 2 for Direct Emissions, Column 3 for Indirect Emissions
from Purchased Energy, and Column 4 for Other Indirect Emissions. Likewise, calculate and enter
Reporting Year Emissions Intensity under Item H.
3. Calculate and Enter Emission Reductions. Calculate emission reductions for direct emissions,
indirect emissions from purchased energy, and other indirect emissions by subtracting the
corresponding Reporting Year intensity (Item H) from the Base Period intensity (Item G) and
multiplying the result by the Reporting Year Output Measure (Item A8, C8, or D8 in Part A, Question
1). Enter the results of these calculations under Item I in the appropriate column: Column 2 for direct
emissions, Column 3 for indirect emissions from purchased energy, and Column 4 for other indirect
emissions. Note that other indirect emission reductions cannot be included in your report as registered
reductions.
4. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to briefly describe each action.
5. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
6. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
July 29, 2010
Voluntary Reporting of Greenhouse Gases
63
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 3 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the Name of Recipient receiving the reduction in Column 1,
enter the emission type distributed (direct, indirect from purchased energy, and other indirect) in
Column 2, enter the units in which the reduction is denominated (metric tons) in Column 4, and enter
the amount of the reduction in Column 5. The reduction distributed must be recorded in carbon
dioxide equivalent; therefore, CO2e has been printed in Column 3. Sum the total direct, indirect, or
other indirect reductions and enter these amounts in the specified Total row.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
64
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B2. Changes in Absolute Emissions
Complete Addendum B2 if you intend to calculate reductions using the changes in absolute emissions
approach for your entity or subentity. Note that to register reductions using this emission reduction
method, your Reporting Year Output must be equal to or greater than your Base Period Average Output.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Output
1. Enter the Physical, Economic, or Indexed Output Measure for Base Period and Reporting
Year. Enter information for the specific output measure you have selected under the appropriate
Item(s) for PHYSICAL (Item A), ECONOMIC (Item B and C), or INDEXED measure (Item D).
Enter Base Period output data in Columns 3-7 and Reporting Year output in Column 8. Note that you
are to enter data for only one output measure type (PHYSICAL, ECONOMIC, or INDEXED),
completing either Item A, Items B and C, or Item D.
a. If a PHYSICAL measure is selected, enter a brief description under output measure (Item A,
Column 1) and indicate the unit of measure in Item A, Column 2. For example, a cement
manufacturer would enter “quantity of cement” under output measure (Column 1) and
“metric tons” under unit of measure (Column 2).
b. If an ECONOMIC measure is selected, enter a brief description under output measure (Items
B and C, Column 1). Provide the output measure in current dollar value(s) under Item B.
Calculate the constant dollar value(s) (in $2000) by multiplying the current value by the GDP
price deflators found in Appendix K and enter under Item C.
c. If an INDEXED measure is selected, enter a brief description of the basis of the INDEXED
measure under output measure (Item D, Column 1). For example, a steel manufacturer could
enter tons of steel or dollar sales of steel. In Item D, Column 2 denote if the index is based on
a physical or economic measure.
d. If reporting Base Period data, enter the value(s) for the PHYSICAL, ECONOMIC, or
INDEXED measure under each of the years in the Base Period columns. If you have a single
year in your Base Period, enter the output value for this year under Year 1 (Column 3). If you
have multiple years in your Base Period, enter the output value for the first year under Year 1
(Column 3), the output value for the second year under Year 2 (Column 4), and so on. See
Section 2.3.1 of the Technical Guidelines for a discussion of selecting the Base Period.
e. If reporting Base Period data, calculate a simple average for the Base Period by summing the
output values reported under Year 1 through Year 4 (Columns 3 through 6) and dividing this
total by the number of years in the Base Period. Enter the result under average (Column 7).
Note that if using INDEXED output measures, the Base Period average (Item D, Column 7)
index number should be set equal to 100.
f. If reporting Reporting Year data, enter the value for the PHYSICAL, ECONOMIC, or
INDEXED measure under the Reporting Year column.
2. Is the Reporting Year Output Equal To or Greater Than the Base Period Average Output?
Check “Yes” or “No.” If No, you may report but not register reductions on this addendum. Go to
Question 4.
3. If Providing an Output Measure Not Described in the Technical Guidelines, Indicate the
Reason Why Alternative Measure Was Selected. If the output measure is not described in the
Technical Guidelines (see Table 2.2 of the Technical Guidelines), use the check boxes to indicate the
reason for selecting an alternate output measure.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
65
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
4. Define and Describe the Output Measure Used and Provide a Rationale for Why This Measure
Was Selected. Use the space provided to define and describe the output measure used.
Part B. Emissions and Emission Reductions
1. Enter Emissions and Calculate Emission Reductions. Enter Base Period emissions data under Item
E and Reporting Year data under Item F in metric tons CO2e as recorded in your entity or subentity
emissions inventory (for an entity Schedule I, Section 2, Part D; for a subentity Addendum A, Part C
as attached in Schedule II, Section 2). Enter the total quantity of direct emissions in Column 2 as
entered in Part C, Item A of your entity or subentity emission inventory. Be sure the direct emissions
include any CO2 captured and sequestered in geologic reservoirs (onsite and offsite). Enter indirect
emissions from purchased energy in Column 3 as recorded in Part D, Item C (Indirect Emissions from
Purchased Energy for Calculation of Emission Reductions) of your entity emissions inventory or Part
C, Item C of your subentity emissions inventory. Enter other indirect emissions in Column 4 as
recorded in Part D, Item H of your entity emissions inventory or Part C, Item H of your subentity
emissions inventory. Calculate direct, indirect from purchased energy and other indirect emission
reductions by subtracting the Reporting Year emissions (as entered in Item F) from the Base Year
emissions (as entered in Item E). Enter the result in either Item G if you intend to register the
emission reductions or Item H if you intend to report but not register the emission reductions.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to briefly describe each action.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the Name of Recipient receiving the reduction in Column 1,
enter the Emission Type distributed (Direct, Indirect from Purchased Energy, and Other Indirect) in
Column 2, enter the Units in which the reduction is denominated (metric tons) in Column 4, and enter
the quantity of the reduction in Column 5. The reduction distributed must be recorded in carbon
dioxide equivalent; therefore, CO2e has been printed under Gas in Column 3. Sum the total direct,
indirect, or other indirect reductions and enter these amounts in the specified Total rows.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
66
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B3. Changes in Carbon Storage
Complete Addendum B3 if you have changes in carbon storage from Schedule I, Section 2, Part B,
Question 4 or from Addendum A, Part B, Question 4, as attached to Schedule II, Section 2. If you are
reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Terrestrial Carbon Flux
1. Enter Reporting Year Inventory of Terrestrial Carbon Flux. If you are reporting for an entity,
enter values for Reporting Year Carbon Stock Change or Carbon Flux from Schedule I, Section 2,
Part B, Question 4h. If you are reporting for a subentity, enter values for Reporting Year Carbon
Stock Change or Carbon Flux from Addendum A, Part B, Question 4h, as attached to Schedule II,
Section 2.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part B. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part B if you have distributed the reductions reported to another reporter to the Voluntary
Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the entity receiving the reduction in Column 1, enter
the units in which the reduction is denominated (metric tons) in Column 3, and the amount of the
reduction in Column 4.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
67
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B4. Changes in Avoided Emissions
Complete Addendum B4 if you intend to calculate reductions resulting from the sale of energy products
using the changes in avoided emissions method for your entity or subentity. If you are reporting
reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Generated Energy Source and Characteristics
1. Did the Entity or Subentity Emit Greenhouse Gases in the Base Period (including any capacity
acquired since the Base Period)? Check “Yes” if your entity or subentity emitted greenhouse gases
in the Base Period. If you have checked “Yes,” you must estimate reductions using Addendum B5,
Emission Reductions from Energy Generation and Distribution and readjust your Base Period to
include any emission sources associated with energy generation capacity acquired since the Base
Period. Check “No” if your entity or subentity emitted no emissions in the Base Period and proceed to
Question 2.
2. Has the Entity or Subentity Acquired or Divested Generation Capacity Since the Base Period?
If your entity or subentity has acquired or divested energy generation capacity since the Base Period,
check “Yes” and proceed to Question 3. Check “No” if energy generating capacity has not been
acquired during the Base Period and proceed to Question 4.
3. Was the Acquired or Divested Capacity Operational During the Base Period for the Entity or
Subentity? Check “Yes” if the added energy generation capacity was operational during the Base
Period. (You must adjust the Base Period Energy Sold to reflect this added capacity.) Check “No” if
the added capacity was not operational during the Base Period.
4. Identify Energy Product Type Sold. Identify the energy product sold by checking the appropriate
box for “Electricity,” “Steam,” “Hot water,” or “Chilled water.”
Part B. Energy Generation, Emissions, and Emission Reductions
1. Activity Data, Emission Coefficients, Conversion Factors, and Emission Reductions.
a. Select Geographic Scope of the Avoided Emissions Benchmark(s) (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 1c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 1a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the appropriately
weighted domestic or foreign electricity and/or thermal avoided emissions benchmark here. You
will need to enter a thermal factor if you are reporting avoided emissions from foreign chilled
water generation. If you are producing chilled water from both electric and natural gas chillers,
enter a weighted thermal factor. Explain how this benchmark was calculated and identify the
July 29, 2010
Voluntary Reporting of Greenhouse Gases
68
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
regions or countries to which it applies. See Appendix N for guidance on determining
benchmarks for purchased thermal energy.
d. Enter Activity Data, Emission Coefficients, Conversion Factors, and Emission Reductions.
For each energy product sold (Columns 2-5), calculate and enter the following activity data,
emission coefficients, conversion factors, and emission reductions in the data table provided:
•
Item A. Base Period Energy Sold. Enter the quantities of electricity (Column 2), steam
(Column 3), hot water (Column 4), and chilled water (Column 5) sold in the Base Period
using the indicated units of measure.
•
Item B. Reporting Year Total Emissions. In metric tons CO2e, enter the quantity of total
emissions associated with producing each energy product sold in the Reporting Year. Enter
the total in Column 6.
•
Item C. Reporting Year Energy Generated. Enter the quantities of electricity (Column 2),
steam (Column 3), hot water (Column 4), and chilled water (Column 5) generated in the
reporting year using the indicated units of measure.
•
Item D. Reporting Year Emissions Intensity. Calculate the reporting year emissions
intensity for each energy product by dividing Item B by Item C using the indicated units of
measure.
•
Item E. Reporting Year Energy Sold. Enter the quantities of electricity (Column 2), steam
(Column 3), hot water (Column 4), and chilled water (Column 5) sold in the Reporting Year
using the indicated units of measure.
•
Item F. Reporting Year Incremental Energy Sold. Calculate the incremental energy sold
in the Reporting Year for each energy product by subtracting Item A from Item E.
•
Item G. Avoided Emissions Intensity Benchmark. Select the appropriate Avoided
Emissions Benchmark for the energy product sold from Appendix F for electricity and
Appendix N for steam and hot and chilled water. Enter the values for electricity (Column 2),
steam (Column 3), hot water (Column 4), and chilled water (Column 5).
•
Item H. Emission Reduction. Calculate the emission reduction for each energy product by
subtracting the Reporting Year emissions intensity (Item D) from the avoided emissions
intensity benchmark (Item G) and multiply the result times the Reporting Year incremental
energy sold (Item F). Calculate the total emission reduction by summing the emission
reduction values in Columns 2 through 5 and enter the result in the total column (Column 6).
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
69
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of recipient receiving the reduction in Column 1, enter
the units in which the reduction is denominated (metric tons or kilograms) in Column 3, and the
quantity of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
70
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B5. Energy Generation and Distribution
Complete Addendum B5 if you intend to calculate reductions resulting from the generation and sale of
energy products by your entity or subentity. You must use this method to estimate reductions rather than
the change in avoided emissions method if your entity or subentity emitted greenhouse gases in the Base
Period.
If you are registering reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Energy Generation and Emissions
1. Energy Product Type Exported. Identify the energy product sold by your entity or subentity by
checking the appropriate box for “Electricity,” “Steam,” “Hot water,” or “Chilled water.”
2. Select Geographic Scope of the Avoided Emissions Benchmark(s) (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
3. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region from
Appendix F. If you will be using an avoided emissions benchmark associated with a single domestic
region (and not a weighted benchmark), enter the number of the region from Appendix F here. Skip to
Question 4 if you will need to use multiple regional benchmarks to calculate your reductions or if the
reductions in the addendum apply to foreign sources. As in Question 2, the regions must be the statebased regions identified in Appendix F of these instructions.
4. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the appropriately
weighted domestic or foreign electricity and/or thermal avoided emissions benchmark here. You will
need to enter a thermal factor if you are reporting avoided emissions from foreign chilled water
generation. If you are producing chilled water from both electric and natural gas chillers, enter a
weighted thermal factor. Explain how this benchmark was calculated and identify the regions or
countries to which it applies. See Appendix N for guidance on determining benchmarks for purchased
thermal energy.
5. Emissions, Energy Generation, and Emissions Intensity. Calculate and enter the following
emissions, energy generation, and emissions intensity data for each energy product sold in the table
provided. Enter values for electricity in Column 2, steam in Column 3, hot water in Column 4, and
chilled water in Column 5.
•
Item A. Base Period Emissions. In metric tons CO2e, enter the quantity of emissions associated
with producing each energy product sold in the Base Period. If you are using a multi-year Base
Period, enter Base Period Average emissions.
•
Item B. Base Period Exported Energy. Enter the quantity of energy exported in the Base Period
for each energy product sold (Columns 2-5) using the indicated units of measure. If you are using
a multi-year Base Period, enter Base Period Average energy exported.
•
Item C. Base Period Emissions Intensity. Calculate the Base Period emissions intensity by
dividing Item A by Item B.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item D. Reporting Year Emissions. In metric tons CO2e, enter the quantity of total emissions
associated with producing each energy product sold in the Reporting Year.
•
Item E. Reporting Year Exported Energy. Enter the quantity of energy exported in the
Reporting Year for each energy product sold (Columns 2-5) using the indicated units of measure.
•
Item F. Reporting Year Emissions Intensity. Calculate the Reporting Year emissions intensity
by dividing Item D by Item E
•
Item G. Reporting Year Incremental Exported Energy. Calculate the incremental energy
exported for each energy product by subtracting Item B from Item E using the indicated units of
measure.
•
Item H. Avoided Emissions Benchmark. Select the appropriate Avoided Emissions Benchmark
for the energy product sold from Appendix F for electricity and Appendix N for steam and hot
and chilled water using the indicated units of measure.
Part B. Emission Reductions
1. Calculate and Enter Emission Reductions. Calculate the following emission reductions and enter
the results in metric tons CO2e in the data table provided:
•
Item I. Emission Reductions From Improvements in Historical Emissions Intensity. Subtract
Reporting Year emissions intensity (Item F) from Base Period emissions intensity (Item C) and
multiply the result by the Base Period exported energy (Item B). Enter the result of this
calculation for each energy product sold in Columns 2 through 5.
•
Item J. Emission Reductions From Incremental Exported Energy. Subtract Reporting Year
emissions intensity (Item F) from the Avoided Emissions Benchmark (Item H) and multiply the
result by the Reporting Year incremental exported energy (Item G). Enter the result of this
calculation for each energy product sold in Columns 2 through 5.
•
Item K. Total Emission Reductions From Energy Generation and Exports. Sum the emission
reduction from improvements in historical emissions intensity (Item I) and the emission reduction
from incremental changes in generation (Item J) and enter the result for each energy product sold
in Columns 2 through 5. Calculate the total emission reduction for all energy products by
summing the values in Columns 2 through 5 and enter the total in Column 6.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
72
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and enter the
quantity of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 3.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
73
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B6. Coal Mine Methane Recovery
Complete Addendum B6 if you are applying the action-specific method for calculating emission
reductions from coal mine methane recovery as described in 2.4.5.6.1 of the Technical Guidelines
pursuant to § 300.8(h)(5) of 10 CFR Part 300 Guidelines for Voluntary Greenhouse Gas Reporting.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Enter Location of Coal Mine(s). Enter the name and location of each coal mine where methane is
recovered.
2. Enter Date Methane Recovery Began. Enter the month and year that methane recovery began. This
is the earliest date when a mine listed in Part A, Question 1 began recovering methane.
3. Describe Action. Describe the action taken in the space provided, explaining its basic nature and
general characteristics, and the manner in which it reduced emissions. Include all information
important to understanding the action and its effects on emissions, as well as any special conditions
necessary to replicate its achievements.
4. Was the Action Reported Last Year. Indicate “Yes” if you included this action (for any of the
mines listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not include the
action(s) in last year’s report, or you did not file a Form EIA-1605 report last year, indicate “No.”
Part B. Action Quantification
1. Enter Action Characteristics. For each coal mine reported in Part A, Question 1, enter the seam
affected, and the month and year that seam was cut through. If multiple seams have been cut through
at a single mine, complete one line of the table for each seam affected.
2. Enter Volume of Gas Captured by Source and Disposition. There are three potential sources of
methane from coal mines: 1) ventilation systems; 2) pre-mining degasification; and 3) other
degasification methods. There are five potential methods for the disposition of gas captured from each
of these sources, which are described below. For each source and disposition method, indicate the
volume captured in each year of your Base Period (Columns 2-5) and the volume captured in the
Reporting Year (Column 7), each expressed in thousand standard cubic feet (Mscf). Calculate and
enter the average volume of gas captured from the affected mines over the Base Period (Column 6).
In the bottom row, sum the total volume of gas captured in each year of your Base Period and the
Reporting Year. Calculate and enter the average total volume of gas captured from the affected mines
over the Base Period.
The methods for disposition of gas recovered from coal mines include:
Flared: Gas is combusted in a flare onsite for the purpose of disposal.
Electricity Generation Used Onsite: Gas is combusted onsite in an internal combustion engine,
gas turbine, or other device to generate electricity and the electricity is used onsite.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Electricity Generation Sold to Grid: Gas is combusted onsite in an internal combustion engine,
gas turbine, or other device to generate electricity and the electricity is sold offsite to an electric
utility or end-use electricity consumer.
Injected Into Pipeline/Sale to Supply Network: Captured gas is injected into a pipeline for sale
offsite to either an end-use consumer or a natural gas transmission and distribution company.
Direct Use Onsite: Captured gas is combusted onsite to meet onsite non-electric energy demand.
3. Enter Average Heat Content of Gas Captured. For each volume of gas entered in Part B, Question
2 for the Base Period and Reporting Year, enter the average heat content, expressed as British thermal
units per standard cubic feet (Btu/scf) (Columns 2-5 and 7). Calculate and enter in units of Btu/scf the
average heat content for gas captured over the Base Period for each source and disposition (Column
6).
4. Enter Total Energy Content of Gas Captured and Combusted. Multiply the volume of gas
captured for each method of disposition (as reported in Part B, Question 2, above) by the average heat
content of the gas captured (as reported in Part B, Question 3, above) by each method of disposition
and then divide that figure by 1,000 to calculate the total Btu captured, expressed as million British
thermal units (MMBtu), for each method of disposition. Enter the product of this calculation for each
year of the Base Period (Columns 2-5) and for the Reporting Year (Column 7). Enter the average total
Btu captured for the Base Period for each method of disposition (Column 6). In the bottom row,
provide the sum of Btu captured for all methods of disposition for each year of the Base Period and
for the Reporting Year. Calculate and enter the average total Btu captured for the Base Period.
5. Enter Mass of Methane Captured. Enter the total mass of methane captured, expressed in metric
tons CO2e for each year of your Base Period (Columns 2-5) and for the Reporting Year (Column 7).
Enter the average mass of methane captured over the Base Period (Column 6). To calculate the mass
of methane captured, use the following steps:
a. Divide the total energy content of gas captured (as reported in Part B, Question 4, above) by
1,005 Btu (the standard heat content of pure methane) and multiply this figure by 1,000,000.
This will yield the volume of methane flared in standard cubic feet (scf).
b. Divide this figure by 1,000 to put it into Mscf (thousand standard cubic feet).
c. Multiply the volume of methane captured by the density of methane (42.28 pounds per Mscf).
This will provide the total weight of methane captured expressed as pounds.
d. Divide total pounds methane by 2204.62 to derive metric tons methane.
e. Convert metric tons methane to metric tons CO2e by multiplying by 25 (the global warming
potential of methane).
Part C. Emission Reductions
1. Calculate Changes in Methane Capture.
•
Item A. Enter the average total mass of methane captured in the Base Period in metric tons CO2e
from Part B, Question 5, Column 6, above.
•
Item B. Enter the total mass of methane captured in the Reporting Year in metric tons CO2e from
Part B, Question 5, Column 7, above.
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U.S. Department of Energy
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Form EIA-1605
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Item C. Enter the difference yielded by subtracting the average mass of methane captured in the
Base Period from the total mass of methane captured in the Reporting Year (B – A).
2. Calculate Changes in Disposition of Electricity Generation From Captured Methane. Enter
information on electricity use onsite and electricity sold offsite under Items D and E, respectively. For
each potential disposition, enter in Columns 2 through 5 the amount of electricity generated, in units
of megawatt-hours (MWh), for each year of your Base Period. In Column 7 enter the amount of
electricity generated (MWh) in the Reporting Year. In Column 6, calculate and enter the average
amount of electricity generated from the captured gas over the Base Period. Calculate and enter total
generation under Item F. For Columns 2 through 5 and 7, sum the total electricity generated in each
year of your Base Period and the Reporting Year, respectively. In Column 6, calculate and enter the
average total generation from the captured gas over the Base Period.
3. Carbon Dioxide Displaced From Electricity Used Onsite (avoided emissions).
a. Select Geographic Scope of the Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 3c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 3a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the
approximately weighted domestic or foreign electricity avoided emissions benchmark here.
Explain how this benchmark was calculated and identify the regions or countries to which it
applies. The avoided emissions benchmark for electricity must be less than or equal to 0.9 metric
tons CO2e/MWh as described in 2.4.4.2.1 of the Technical Guidelines.
d. Calculate Carbon Dioxide Displaced From Electricity Used Onsite.
•
Item G. Enter the average MWh of electricity used onsite for your Base Period from Part C,
Question 2, Item D, Column 6, above.
•
Item H. Enter the total MWh of electricity used onsite for your Reporting Year from Part C,
Question 2, Item D, Column 7, above.
•
Item I. Calculate and enter the Reporting Year incremental electricity used onsite by
subtracting the average MWh of electricity used onsite in your Base Period (Item G) from the
total MWh used onsite in the Reporting Year (Item H). If the incremental amount is negative,
no reductions were generated in your Reporting Year from electricity used onsite; therefore,
you may skip to Part C, Question 4.
•
Item J. Enter the total emissions (metric tons CO2e) from electricity used onsite during the
Reporting Year.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item K. Calculate and enter the emissions intensity of electricity used onsite during the
Reporting Year by dividing Item J (metric tons CO2e) by Item H (MWh).
•
Item L. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in Question 3c above.
•
Item M. Calculate your Emission Reductions (metric tons CO2e) by subtracting Item K from
Item L, and multiplying the result by Item I.
4. Carbon Dioxide Displaced From Electricity Sales (avoided emissions).
a. Select Geographic Scope of the Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 4c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 4a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the
approximately weighted domestic or foreign electricity avoided emissions benchmark here.
Explain how this benchmark was calculated and identify the regions or countries to which it
applies. The avoided emissions benchmark for electricity must be less than or equal to 0.9 metric
tons CO2e/MWh as described in 2.4.4.2.1 of the Technical Guidelines.
5. Calculate Carbon Dioxide Displaced From Electricity Sales.
•
Item N. Enter the average electricity sales during your Base Period (MWh) from Part C,
Question 2, Item E, Column 6.
•
Item O. Enter the electricity sales during your Reporting Year (MWh) from Part C, Question
2, Item E, Column 7.
•
Item P. Calculate and enter the incremental amount of electricity (MWh) sold in the
Reporting Year by subtracting the average MWh of electricity sold in your Base Period (Item
N) from the total MWh sold in the Reporting Year (Item O). If the incremental amount is
negative, and no reductions were generated in your Reporting Year from electricity sales, you
may skip to Part C, Question 5.
•
Item Q. Enter the total emissions (metric tons CO2e) from electricity sold during the
Reporting Year.
•
Item R. Calculate and enter the emissions intensity of electricity sold during the Reporting
Year by dividing Item Q (metric tons CO2e) by Item O (MWh).
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item S. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in Question 4c above.
•
Item T. Calculate your emission reductions (metric tons CO2e) by subtracting Item R from
Item S, and multiplying the result by Item P.
6. Calculate Changes in Carbon Dioxide Emissions From Flaring.
•
Item U. Enter Base Period average methane flared (MMBtu) from Part B, Question 4,
Column 6.
•
Item V. Enter Reporting Year quantity of methane flared (MMBtu) from Part B, Question 4,
Column 7.
•
Item W. Calculate and enter the change in methane flared (MMBtu) by subtracting Item U
from Item V.
•
Item X. Calculate the change in carbon dioxide emissions from flaring by converting
methane to metric tons CO2e using the following steps:
a. Divide the heat content (as reported in Item W, above) by 1,005 Btu (the standard heat
content of pure methane) and multiply this figure by 1,000,000. This will yield the
volume of methane flared in standard cubic feet.
b. Divide this figure by 1,000 to put it into Mscf (thousand standard cubic feet)
c. Multiply the volume of methane captured by the density of methane (42.28 pounds per
Mscf). This will provide the total weight of methane captured expressed as pounds.
d. Divide total pounds methane by 2204.62 to derive metric tons methane.
e. Convert metric tons methane to metric tons carbon dioxide equivalent by multiplying by
25 (the global warming potential of methane).
7. Summarize Emission Reductions.
•
Item Y. In the Direct and TOTAL Columns, enter the increase in methane captured value
(metric tons CO2e) from Item C.
•
Item Z. In the Avoided and TOTAL Columns, enter the carbon dioxide displaced from
electricity used onsite value (metric tons CO2e) from Item M.
•
Item AA. In the Avoided and TOTAL Columns, enter the carbon dioxide displaced from
electricity sales value (metric tons CO2e) from Item T.
•
Item BB. In the Direct and TOTAL Columns, enter the change in carbon dioxide emissions
from flaring (metric tons CO2e) from Item X.
•
Item CC. Calculate and enter the net change in greenhouse gas emissions. In the TOTAL
Column, add Items Y, Z, and AA, and subtract Item BB from the sum. Enter the result in the
TOTAL Column in Row CC.
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
8. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
9. Identify Cause(s) of the Emission Reduction(s). Check the applicable check boxes corresponding to
the causes of the emission reductions achieved by your entity or subentity. If the reduction is the
result of a government requirement, check the applicable requirement types (Federal, State and/or
Local). If you are reporting for a foreign subentity and the reductions were caused by a requirement
of a foreign government, check “Government requirement” and “Local requirement.”
10. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 6 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and the quantity of
the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide equivalent;
therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
79
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B7. Landfill Methane Recovery
Complete Addendum B7 if you are using the action-specific method for calculating emission reductions
from landfill methane recovery as described in 2.4.5.6.2 of the Technical Guidelines pursuant to
§300.8(h)(5) of 10 CFR Part 300 Guidelines for Voluntary Greenhouse Gas Reporting.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Enter Location of Landfill(s). Enter the name and location of each landfill where methane recovery
occurred.
2. Enter Date Methane Recovery Began. Enter the month and year the methane recovery was
initiated. This is the earliest date when a landfill listed in Part A, Question 1 began capturing
methane.
3. Describe Action. Describe the action taken in the space provided, explaining its basic nature, general
characteristics, and the manner in which it reduced emissions. Include all information important to
understanding the action and its effects on emissions, as well as any special conditions necessary to
replicate its achievements.
4. Was the Action Reported Last Year. Indicate “Yes” if you included this action (for any of the
landfills listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not include the
action(s) in last year’s report, or you did not file a Form EIA-1605 report last year, indicate “No.”
Part B. Action Quantification
1. Enter Action Characteristics. For each landfill reported in Part A, Question 1, enter the year the
landfill opened and the year the landfill was closed, if it has closed. Also enter the year a gas recovery
system was put into place and an estimate of waste in place in the landfill at the end of the Reporting
Year in million metric tons of waste.
2. Enter Volume of Gas Captured and Disposition. There are six potential methods for the
disposition of captured gas, which are described below. For each method, indicate the volume
captured in each year of your Base Period (Columns 2-5) and the volume captured in the Reporting
Year (Column 7), each expressed in thousand standard cubic feet (Mscf). Calculate and enter the
average volume of gas captured from the affected facilities over the Base Period (Column 6). In the
bottom row, sum the total volume of gas captured in each year of your Base Period and the Reporting
Year. Calculate and enter the average total volume of gas captured from the affected facilities over
the Base Period.
The methods for disposition of gas from landfills include:
Flared: Gas is combusted in a flare onsite for the purpose of disposal.
Electricity Generation Used Onsite: Gas is combusted onsite in an internal combustion
engine, gas turbine, or other device to generate electricity and the electricity is used onsite.
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Electricity Generation Sold Offsite: Gas is combusted onsite in an internal combustion
engine, gas turbine, or other device to generate electricity and the electricity is sold offsite to
an electric utility or end-use electricity consumer.
Injected Into Pipeline/Sale to Supply Network: Captured gas is cleaned and upgraded to
match pipeline gas specifications, and is injected into a pipeline for sale offsite to either an
end-use consumer or a natural gas transmission and distribution company.
Direct Use Onsite: Captured gas is combusted onsite to meet onsite non-electric energy
demand.
Direct Use Offsite: Captured gas is transported offsite and combusted as a medium-Btu fuel
for meeting non-electric energy demand.
3. Enter Average Heat Content of Gas Captured. For each volume of gas entered in Part B, Question
2 for the Base Period and Reporting Year, enter the average heat content, expressed as British thermal
units per standard cubic feet (Btu/scf) (Columns 2-5 and 7). Calculate and enter in units of Btu/scf the
average heat content for gas captured over the Base Period for each source and disposition (Column
6).
4. Enter Total Energy Content of Gas Captured and Combusted. Multiply the volume of gas
captured for each method of disposition (as reported in Part B, Question 2, above) by the average heat
content of the gas captured (as reported in Part B, Question 3, above) by each method of disposition
and then divide that figure by 1,000 to calculate the total Btu captured, expressed as million British
Thermal Units (MMBtu), for each method of disposition. Enter the product of this calculation for
each year of the Base Period (Columns 2-5) and for the Reporting Year (Column 7). Enter the
average total Btu captured for the Base Period for each method of disposition (Column 6). In the
bottom row, provide the sum of Btu captured for all methods of disposition for each year of the Base
Period and for the Reporting Year. Calculate and enter the average total Btu captured for the Base
Period.
5. Enter Mass of Methane Captured. Enter the total mass of methane captured, expressed in metric
tons carbon dioxide equivalent (metric tons CO2e) for each year of your Base Period (Columns 2-5)
and for the Reporting Year (Column 7). Enter the average mass of methane captured over the Base
Period (Column 6). To calculate the mass of methane captured, use the following steps:
a. Divide the energy content of gas captured (as reported in Part B, question 4, above) by 1,005
Btu (the standard heat content of pure methane) and multiply this number by 1,000,000. This
will yield the volume of methane flared in standard cubic feet.
b. Divide this figure by 1,000 to put it in Mscf (thousand standard cubic feet).
c. Multiply the volume of methane captured by the density of methane (42.28 pounds per Mscf).
This will provide the total weight of methane captured expressed as pounds.
d. Divide total pounds methane by 2204.62 to derive metric tons methane.
e. Convert metric tons methane to metric tons CO2e by multiplying by 25 (the global warming
potential of methane).
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Part C. Emission Reductions
1. Calculate Changes in Methane Capture
•
Item A. Enter the average total mass of methane captured in the Base Period in metric tons CO2e
from Part B, Question 5, Column 6, above.
•
Item B. Enter the total mass of methane captured in the Reporting Year in metric tons CO2e from
Part B, Question 5, Column 7, above.
•
Item C. Enter the difference yielded by subtracting the average mass of methane captured in the
Base Period from the total mass of methane captured in the Reporting Year (B – A).
2. Calculate Changes in Disposition of Electricity Generation From Captured Methane. Enter
information on electricity use onsite and electricity sold offsite under Items D and E, respectively. For
each potential disposition, enter in Columns 2 through 5 the amount of electricity generated, in units
of megawatt-hours (MWh), in each year of your Base Period. In Column 7, enter the amount of
electricity generated (MWh) in the Reporting Year. In Column 6, calculate and enter the average
amount of electricity generated from the captured gas over the Base Period. Calculate and enter total
generation under Item F. For Columns 2 through 5 and 7, sum the total electricity generated in each
year of your Base Period and the Reporting Year, respectively. In Column 6, calculate and enter the
average total generation from the captured gas over the Base Period.
3. Carbon Dioxide Displaced From Electricity Used Onsite (avoided emissions).
a. Select Geographic Scope of the Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 3c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 3a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the
approximately weighted domestic or foreign electricity avoided emissions benchmark here.
Explain how this benchmark was calculated and identify the regions or countries to which it
applies. The avoided emissions benchmark for electricity must be less than or equal to 0.9 metric
tons CO2e/MWh as described in 2.4.4.2.1 of the Technical Guidelines.
d. Calculate Carbon Dioxide Displaced From Electricity Used Onsite.
•
July 29, 2010
Item G. Enter the average MWh of electricity used onsite for your Base Period from Part C,
Question 2, Item D, Column 6, above.
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item H. Enter the total MWh of electricity used onsite for your Reporting Year from Part C,
Question 2, Item D, Column 7, above.
•
Item I. Calculate and enter the Reporting Year incremental electricity used onsite by
subtracting the average MWh of electricity used onsite in your Base Period (Item G) from the
total MWh used onsite in the Reporting Year (Item H). If the incremental amount is negative,
no reductions were generated in the Reporting Year from electricity used onsite; therefore,
you may skip to Part C, Question 4.
•
Item J. Enter the total emissions (metric tons CO2e) from electricity used onsite during the
Reporting Year. Note: Include emissions from supplemental fossil fuel use only. If there was
no supplemental fossil fuel used, enter zero.
•
Item K. Calculate and enter the emissions intensity of electricity used onsite during the
Reporting Year by dividing Item J (metric tons CO2e) by Item H (MWh). If there was no
supplemental fossil fuel used, enter zero.
•
Item L. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in 3c above.
•
Item M. Calculate your emission reductions (metric tons CO2e) by subtracting Item K from
Item L, and multiplying the result by Item I.
4. Carbon Dioxide Displaced From Electricity Sales (avoided emissions).
a. Select Geographic Scope of Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regional distinctions
should be based on the EIA regions in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Region from Appendix F.
If you will be using an avoided emissions benchmark associated with a single domestic region
(and not a weighted benchmark), enter it here. Skip to Question 4c if you will need to use
multiple regional benchmarks to calculate your reductions or if the reductions in the addendum
apply to foreign sources. As in Question 4a, the regional distinctions should be based on the EIA
regions in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark and Briefly Explain How it was Calculated. Enter the appropriately
weighted domestic or foreign avoided emissions benchmark here. You will need to explain how
this benchmark was calculated and the regions to which it applies. The avoided emissions
benchmark for electricity must be less than or equal to 0.9 metric tons CO2e/MWh as described in
2.4.4.2.1 of the Technical Guidelines.
d. Calculate Carbon Dioxide Displaced From Electricity Sales.
•
July 29, 2010
Item N. Enter the average electricity sales during your Base Period (MWh) from Part C,
Question 2, Item E, Column 6.
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
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Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item O. Enter the electricity sales during your Reporting Year (MWh) from Part C, Question
2, Item E, Column 7.
•
Item P. Calculate and enter the incremental amount of electricity (MWh) sold in the
Reporting Year by subtracting the average MWh of electricity sold in your Base Period (Item
N) from the total MWh sold in the Reporting Year (Item O). If the incremental amount is
negative, no reductions were generated in your Reporting Year from electricity sales, and you
may skip to Part C, Question 5.
•
Item Q. Enter the total emissions (metric tons CO2e) from electricity sold during the
Reporting Year. Note: Include emissions from supplemental fossil fuel use only. If there was
no supplemental fossil fuel used, enter zero.
•
Item R. Calculate and enter the emissions intensity of electricity sold during the Reporting
Year by dividing Item Q (metric tons CO2e) by Item O (MWh). If there was no supplemental
fossil fuel used, enter zero.
•
Item S. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in 4c above.
•
Item T. Calculate your Emissions Reductions (metric tons CO2e) by subtracting Item R from
Item S, and multiplying the result by Item P.
5. Calculate Carbon Dioxide Emission Displaced by Methane Supplied to a Natural Gas
Distribution Network.
•
Item U. Enter the average annual quantity of methane supplied to a natural gas distribution
network in the Base Period in MMBtu.
•
Item V. Enter the quantity of methane supplied to a natural gas distribution network in the
Reporting Year in MMBtu.
•
Item W. Calculate the incremental quantity of methane supplied to a natural gas distribution
network by subtracting Item U from Item V. Enter the result in Item W, Column 3.
•
Item X. Enter the emissions factor for natural gas from Appendix H.
•
Item Y. Calculate the CO2 emissions displaced by methane supplied to a natural gas
distribution network by multiplying Item W by Item X. Enter the result under Item Y,
Column 3.
6. Summarize Emission Reductions.
•
Item Z. In the Direct and TOTAL Columns (Columns 3 and 6), enter the increase in methane
captured value (metric tons CO2e) from Item C.
•
Item AA. In the Avoided and TOTAL Columns (Columns 5 and 6), enter the carbon dioxide
displaced from electricity used onsite value (metric tons CO2e) from Item M.
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item BB. In the Avoided and TOTAL Columns (Columns 5 and 6), enter the carbon dioxide
displaced from electricity sales value (metric tons CO2e) from Item T.
•
Item CC. In the Indirect and TOTAL Columns (Columns 4 and 6), enter the carbon dioxide
emissions displaced by methane supplied to a natural gas distribution network from Item Y.
•
Item DD. Add the values in the TOTAL Column entered under Items Z, AA, BB, and CC
and enter the result in Item DD TOTAL Column.
7. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
8. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
9. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 5 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and the enter
quantity of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
85
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B8. Geologic Sequestration
Complete Addendum B8 when using the action-specific method for calculating emission reductions from
geologic sequestration of carbon dioxide as described in 2.4.5.6.5 of the Technical Guidelines pursuant to
§300.8(h)(5) of 10 CFR Part 300 Guidelines for Voluntary Greenhouse Gas Reporting.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Enter the Name and Location of CO2 Injection Project. Enter the name, location, and
characteristics of each facility where geologic sequestration occurred.
2. Enter the Date CO2 Injection Began. Enter the month and year the action was initiated. This is the
earliest date when a facility listed in Part A, Question 1 began CO2 injection for geologic
sequestration.
3. Describe the Action. Describe the action taken in the space provided, explaining its basic nature and
general characteristics, and the manner in which it reduced emissions. Include all information
important to understanding the action and its effects on emissions, as well as any special conditions
necessary to replicate its achievements.
4. Was the Action Reported Last Year? Indicate “Yes” if you included this action (for any of the
injection projects listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not
include the action(s) in last year’s report, or you did not file a Form EIA-1605 report last year,
indicate “No.”
5. Is the Reporting Entity Responsible for the Injection of CO2 Into a Permanent Storage
Reservoir? Check “Yes” or “No” to indicate whether the entity is responsible.
6. If Answer to Question 5 is No, Does Reporter Have a Written Agreement With the Sequestering
Party Allowing the Reporter to Claim the Reductions? Check the appropriate box. If “Notapplicable,” enter an explanation in the space provided.
Part B. Action Quantification
1. Enter Source of Carbon Dioxide Sequestered in Current Reporting Year. Complete a row for
each different source of carbon dioxide captured or acquired in the current Reporting Year. Enter the
name of each source in Column 1 and its location in Column 2. Enter the quantity of carbon dioxide
captured from anthropogenic sources in Column 3 and the quantity of anthropogenic CO2 acquired
via transfer or purchase from another entity in Column 4. Enter the quantity acquired via transfer or
purchase from another entity (for which the entity is deemed responsible through a written
agreement). An entity should only claim reductions for CO2 acquired and sequestered in accordance
with a written agreement. Enter the total carbon dioxide obtained from each source in Column 5.
Include in Column 6 the name of the ultimate storage site where each quantity of carbon dioxide was
sequestered. In Item B, sum the quantities of carbon dioxide and indicate the unit of measure. Enter
all carbon dioxide quantities in metric tons CO2e.
2. Enter Amount Sequestered in Current Reporting Year. For each storage site where carbon
dioxide was sequestered in the current Reporting Year, complete a new row starting with Item C1 if
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U.S. Department of Energy
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
the carbon dioxide was sequestered by the entity, and starting with Item D1 if the carbon dioxide was
sequestered by a third party. Indicate whether the carbon dioxide was injected for enhanced resource
recovery, and enter the quantity injected, the quantity that leaked, the monitoring method used, and
the net carbon dioxide sequestered during the current Reporting Year. In Row E, sum the quantities of
carbon dioxide. Enter all carbon dioxide quantities in metric tons CO2e.
3. Enter the Average Amount Sequestered in Base Period. For each storage site where carbon
dioxide was sequestered in the Base Period, complete a new row starting with Item F1 if the carbon
dioxide was sequestered by the entity, and starting with Item G1 if the carbon dioxide was
sequestered by a third party. Indicate whether the carbon dioxide was injected for enhanced resource
recovery, and enter the average annual quantity injected, the average annual quantity that leaked, the
monitoring method used, and the average annual net carbon dioxide sequestered during the Base
Period. In Row H, sum the quantities of carbon dioxide. Enter all carbon dioxide quantities in metric
tons CO2e.
Part C. Emission Reductions
1. Calculate Emission Reductions. For Item I, subtract the total carbon dioxide sequestered in the Base
Year (Item H7) from the total carbon dioxide sequestered in the current Reporting Year (Item E7) to
yield the total emission reductions expressed in metric tons CO2e.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.
4. Summarize Benefits and Costs of the Actions Taken to Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 1, above to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b))
Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and enter the
quantity of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B9. Electricity Transmission and Distribution Improvements
Complete Addendum B9 if you intend to calculate reductions resulting from improvements to your
electricity transmission and distribution (T&D) system.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Date Action Was Initiated. Enter the month and year when the earliest improvement to the T&D
system was completed and operational in the space provided.
2. Did You Report Transmission and Distribution Improvements Last Year? Indicate whether you
have submitted information on T&D improvements affecting the T&D system included in your entity
or subentity report in a previous Reporting Year by checking “Yes” or “No.”
3. Are You Reporting as a Control Area or as a Member of a Control Area? Indicate whether you
are reporting as a control area or as a member of a control area by checking “Yes” or “No.”
Part B. Activity Data
1. Enter Activity Data. Enter the following Base Period and Reporting Year activity data in the table
provided. Enter the unit of measure used (kWh [kilowatthours] or kVAh [kilovolt-ampere hours]) in
Column 2 for each item.
a. Enter Base Period Activity Data
•
Item A. Electricity Entering T&D System From Own Generation. Enter the average
annual quantity of electricity generated by your entity that entered the T&D system during
the Base Period in Column 3.
•
Item B. Electricity Delivered Through T&D System to End Users. Enter the average
annual quantity of electricity delivered to end users through the T&D system during the Base
Period in Column 3.
•
Item C. Electricity Imported Into T&D System. Enter the average annual quantity of
electricity generated by other entities and imported into your entity or subentity’s T&D
system during the Base Period in Column 3.
•
Item D. Electricity Exported From T&D System. Enter the average annual quantity of
electricity exported to other entities from your entity or subentity’s T&D system during the
Base Period in Column 3.
•
Item E. Net Imports of Electricity. Calculate net imports of electricity in the Base Period by
subtracting electricity exported from your T&D system (Item D) from the electricity imported
into your T&D system (Item C). Enter the result in Column 3.
July 29, 2010
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U.S. Department of Energy
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item F. Actual Net Interchange (ANI) if Reporting on Control Area Basis. If you are
reporting as a control area or as a member of a control area, enter the annual average Actual
Net Interchange (ANI) for the Base Period in Column 3.
•
Item G. Loss Ratio. Calculate the Base Period Loss Ratio using the Equation 1 below (or
Equation 2 below, if reporting as a control area or as a member of a control area). The letters
in these equations refer to the item designations above (e.g., A = Electricity Entering T&D
System from Own Generation). Enter the result in Item G, Column 3.
(A + E - B) / (A + E) (Equation 1)
[A - (B + F)] / (A - F) (Equation 2)
b. Enter Reporting Year Activity Data
•
Item H. Electricity Entering T&D System From Own Generation. Enter quantity of
electricity generated by your entity that entered the T&D system during the Reporting Year in
Column 3.
•
Item I. Electricity Delivered Through T&D System to End Users. Enter the quantity of
electricity delivered to end users through the T&D system during the Reporting Year in
Column 3.
•
Item J. Electricity Imported Into T&D System. Enter the quantity of electricity generated
by other entities and imported into your entity or subentity’s T&D system during the
Reporting Year in Column 3.
•
Item K. Electricity Exported From T&D System. Enter the quantity of electricity exported
to other entities from your entity or subentity’s T&D system during the Reporting Year in
Column 3.
•
Item L. Net Imports of Electricity. Calculate net imports of electricity in the Reporting
Year by subtracting electricity exported from your T&D system (Item K) from the electricity
imported into your T&D system (Item J). Enter the result in Column 3.
•
Item M. Actual Net Interchange (ANI) if Reporting on Control Area Basis. If you are
reporting as a control area or as a member of a control area, enter the Actual Net Interchange
(ANI) for the Reporting Year in Column 3.
•
Item N. Loss Ratio. Calculate the Reporting Year loss ratio using the Equation 3 below (or
Equation 4 below, if reporting as a control area or as a member of a control area). The letters
in these equations refer to the item designations above (e.g., H = Average Annual Electricity
Entering T&D System from Own Generation in Reporting Year). Enter the result in Column
3.
(H + L - I) / (H + L) (Equation 3)
[H - (I + M)] / (H - M) (Equation 4)
c. Item O. Change in Loss Intensity. Calculate the change in loss intensity using Equation 5 below
(or Equation 6 below, if reporting as a control area or as a member of a control area). The letters
in these equations refer to the item designations above (e.g., H = Electricity Entering T&D
System from Own Generation in Reporting Year). Enter the result in Column 3.
(G - N) * (H + L) (Equation 5)
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
(G - N) * (H - M) (Equation 6)
Part C. Emission Reductions
1. Select Geographic Scope of the Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
2. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region from
Appendix F. If you will be using an avoided emissions benchmark associated with a single domestic
region (and not a weighted benchmark), enter the number of the region from Appendix F here. Skip to
Question 3 if you will need to use multiple regional benchmarks to calculate your reductions or if the
reductions in the addendum apply to foreign sources. As in Question 1, the regions must be the statebased regions identified in Appendix F of these instructions.
3. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the approximately
weighted domestic or foreign electricity avoided emissions benchmark here. Explain how this
benchmark was calculated and identify the regions or countries to which it applies. The avoided
emissions benchmark for electricity must be less than or equal to 0.9 metric tons CO2e/MWh as
described in 2.4.4.2.1 of the Technical Guidelines.
4. Calculate Emission Reductions.
a. Item P. Avoided Emissions Benchmark for Electricity. Enter the appropriate Avoided
Emissions Benchmark for electricity from Appendix F (for a single U.S. region) or the
weighted/foreign benchmark as entered in Question 3 above.
b. Item Q. System Power Factor. If you are calculating loss intensity in kVAh, enter the power
factor for your T&D system, if known. If this power factor is greater than 0.95, enter 0.95. If you
do not know the power factor for your T&D system, enter a default value of 0.90.
c. Item R. Total Emission Reductions. Calculate total emission reductions using Equation 7 below
(or Equation 8 below, if reporting as a control area or as a member of a control area). Enter the
result in Column 3.
(O * P) / 1000 (Equation 7)
[O * (P * Q)] / 1000 (Equation 8)
d. Item S. Direct Emission Reductions. Calculate the quantity of total emission reductions
attributable to direct emission sources using equation 9 below and enter the result in Column 3.
R * [I / (I + L)] (Equation 9)
e. Item T. Avoided Emissions. Calculate the quantity of total emission reductions attributable to
avoided electricity imports (avoided emissions) using equation 10 below. Enter the result in
Column 3.
R + [L / (I + L)] Equation 10
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
5. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
6. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
7. Summarize Benefits and Costs of the Actions Taken to Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the entity receiving the reduction in Column 1, enter
the units in which the reduction is denominated (metric tons) in Column 3, and enter the quantity of
the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide equivalent;
therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
91
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B10. Capture of Methane From Anaerobic Digestion at Wastewater
Treatment Facilities
Complete Addendum B10 when using the action-specific method for calculating emission reductions
from the capture of methane from anaerobic digestion at wastewater treatment facilities as described in
2.4.5.6.3 of the Technical Guidelines pursuant to §300.8(h)(5) of 10 CFR Part 300 Guidelines for
Voluntary Greenhouse Gas Reporting.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Enter Locations of Wastewater Treatment Facilities. Enter the name and location of each facility
where methane capture occurred.
2. Enter Date Anaerobic Digester Use Began. Enter the month and year the action was initiated. This
is the earliest date when a facility listed in Part A, Question 1 began capturing methane.
3. Describe Action. Describe the action taken in the space provided, explaining its basic nature and
general characteristics, and the manner in which it reduced emissions. Include all information
important to understanding the action and it effects on emissions, as well as any special conditions
necessary to replicate its achievements.
4. Was the Action Reported Last Year? Indicate “Yes” if you included this action (for any of the
facilities listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not include the
action(s) in last year’s report, or you did not file a Form EIA-1605 report last year, indicate “No.”
Part B. Action Quantification
1. Enter Volume of Gas Captured and Disposition. There are five potential methods for the
disposition of captured gas, which are described below. For each method, indicate the volume
captured (Mscf) in each year of your Base Period (Columns 2-5) and the volume (Mscf) captured in
the Reporting Year (Column 7). Calculate and enter the average volume of gas captured from the
affected facilities over the Base Period (Column 6). In the bottom row, sum the total volume of gas
captured in each year of your Base Period and the Reporting Year. Calculate and enter the average
total volume of gas captured from the affected facilities over the Base Period.
The methods for disposition of gas from anaerobic digestion of wastewater include:
Flared: Gas is combusted in a flare onsite for the purpose of disposal.
Electricity Generation: Gas is combusted onsite in an internal combustion engine, gas turbine, or
other device to generate electricity and the electricity is used onsite or sold offsite to an electric
utility or end-use electricity consumer.
Injected Into Pipeline/Sale to Supply Network: Captured gas is cleaned and upgraded to match
pipeline gas specifications, and is injected into a pipeline for sale offsite to either an end-use
consumer or a natural gas transmission and distribution company.
Direct Use Onsite: Captured gas is combusted onsite to meet onsite non-electric energy demand.
July 29, 2010
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U.S. Department of Energy
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Direct Use Offsite: Captured gas is transported offsite and combusted as a medium-Btu fuel for
meeting non-electric energy demand.
2. Enter Average Heat Content of Gas Captured and Utilized. For each volume of gas entered in
Part B, Question 1, above for the Base Period and Reporting Year, enter the average heat content,
expressed as British thermal units per standard cubic feet (Btu/scf) (Columns 2-5 and 7). Calculate
and enter in units of Btu/scf the average heat content for gas captured over the Base Period for each
source and disposition (Column 6).
3. Enter Total Energy Content of Gas Captured and Utilized. Multiply the volume of gas captured
for each method of disposition (as reported in Part B, Question 1, above) by the average heat content
of the gas captured (as reported in Part B, Question 2, above) and divide this figure by 1,000 to
calculate the total Btu captured, expressed as million British thermal units (MMBtu), for each method
of disposition. Enter the product of the multiplication for each year of the Base Period (Columns 2-5)
and for the Reporting Year (Column 7). Enter the average total Btu captured for the Base Period for
each method of disposition (Column 6). In the bottom row, provide the sum of Btu captured for all
methods of disposition for each year of the Base Period and for the Reporting Year. Calculate and
enter the average total Btu captured for the Base Period.
4. Enter Mass of Methane Captured and Utilized. Enter the total mass of methane captured,
expressed in metric tons CO2e for each year of your Base Period and for the Reporting Year. Enter
the average mass of methane captured over the Base Period. To calculate the mass of methane
captured, use the following steps:
•
•
•
•
•
Divide the energy content of gas captured (as reported in Question 3, above) by 1,005 Btu
(the standard heat content of pure methane) and multiply by 1,000,000. This will yield the
volume of methane flared in standard cubic feet.
Divide this figure by 1,000 to put it in Mscf (thousands of standard cubic feet).
Multiply the volume of methane captured by the density of methane (42.28 pounds per Mscf).
This will provide the total weight of methane captured expressed as pounds.
Divide total pounds methane by 2204.62 to derive metric tons methane.
Convert metric tons methane to metric tons CO2e by multiplying by 25 (the global warming
potential of methane).
5. Enter Nitrous Oxide Emissions From Aerobic Conditions During Base Period and Reporting
Year. For domestic wastewater treatment facilities, calculate nitrous oxide emissions from domestic
wastewater effluent during the Base Period and Reporting Year, as described in 1.E.4.3.2 of the
Technical Guidelines.
Part C. Emission Reductions
1. Calculate Changes in Methane Captured and Utilized
•
Item A. Enter the average total mass of methane captured in the Base Period in metric tons CO2e
from Part B, Question 4, Column 6, above.
•
Item B. Enter the total mass of methane captured in the Reporting Year in metric tons CO2e from
Part B, Question 4, Column 7, above.
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Item C. Enter the difference yielded by subtracting the average mass of methane captured in the
Base Period from the total mass of methane captured in the Reporting Year (B – A).
2. Calculate Changes in Disposition of Electricity Generation From Captured Methane. Enter
information on electricity use onsite and electricity sold offsite under Items D and E, respectively. For
each potential disposition, enter in Columns 2 through 5 the amount of electricity generated, in units
of megawatt-hours (MWh), in each year of your Base Period. In Column 7 enter the amount of
electricity generated (MWh) in the Reporting Year. In Column 6, calculate and enter the average
amount of electricity generated from the captured gas over the Base Period. Calculate and enter total
generation under Item F. For Columns 2 through 5 and 7, sum the total electricity generated in each
year of your Base Period and the Reporting Year, respectively. In Column 6, calculate and enter the
average total generation from the captured gas over the Base Period.
3. Carbon Dioxide Displaced From Electricity Used Onsite (avoided emissions).
a. Select Geographic Scope of the Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 3c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 3a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the
approximately weighted domestic or foreign electricity avoided emissions benchmark here.
Explain how this benchmark was calculated and identify the regions or countries to which it
applies. The avoided emissions benchmark for electricity must be less than or equal to 0.9 metric
tons CO2e/MWh as described in 2.4.4.2.1 of the Technical Guidelines.
d. Calculate Carbon Dioxide Displaced From Electricity Used Onsite.
•
Item G. Enter the average MWh of electricity used onsite for your Base Period from Part C,
Question 2, Item D, Column 6, above.
•
Item H. Enter the total MWh of electricity used onsite for your Reporting Year from Part C,
Question 2, Item D, Column 7, above.
•
Item I. Calculate and enter the Reporting Year incremental electricity used onsite by
subtracting the average MWh of electricity used onsite in your Base Period (Item G) from the
total MWh used onsite in the Reporting Year (Item H). If the incremental amount is negative,
no reductions were generated in the Reporting Year from electricity used onsite; therefore,
you may skip to Part C, Question 4.
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item J. Enter the total emissions (metric tons CO2e) from electricity used onsite during the
Reporting Year. Note: Include emissions from supplemental fossil fuel use only. If there was
no supplemental fossil fuel used, enter zero.
•
Item K. Calculate and enter the emissions intensity of electricity used onsite during the
Reporting Year by dividing Item J (metric tons CO2e) by Item H (MWh). If there was no
supplemental fossil fuel used, enter zero.
•
Item L. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in 3c above.
•
Item M. Calculate your emission reductions (metric tons CO2e) by subtracting Item K from
Item L, and multiplying the result by Item I.
4. Carbon Dioxide Displaced From Electricity Sales (avoided emissions).
a. Select Geographic Scope of the Avoided Emissions Benchmark (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 4c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 4a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How It Was Calculated. Enter the
approximately weighted domestic or foreign electricity avoided emissions benchmark here.
Explain how this benchmark was calculated and identify the regions or countries to which it
applies. The avoided emissions benchmark for electricity must be less than or equal to 0.9 metric
tons CO2e/MWh as described in 2.4.4.2.1 of the Technical Guidelines.
d. Calculate Carbon Dioxide Displaced From Electricity Used Onsite.
•
Item N. Enter the average MWh of electricity used onsite for your Base Period from Part C,
Question 2, Item D, Column 6, above.
•
Item O. Enter the total MWh of electricity used onsite for your Reporting Year from Part C,
Question 2, Item D, Column 7, above.
•
Item P. Calculate and enter the Reporting Year incremental electricity used onsite by
subtracting the average MWh of electricity used onsite in your Base Period (Item G) from the
total MWh used onsite in the Reporting Year (Item H). If the incremental amount is negative,
no reductions were generated in the Reporting Year from electricity used onsite; therefore,
you may skip to Part C, Question 5.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item Q. Enter the total emissions (metric tons CO2e) from electricity used onsite during the
Reporting Year. Note: Include emissions from supplemental fossil fuel use only. If there was
no supplemental fossil fuel used, enter zero.
•
Item R. Calculate and enter the emissions intensity of electricity used onsite during the
Reporting Year by dividing Item J (metric tons CO2e) by Item H (MWh). If there was no
supplemental fossil fuel used, enter zero.
•
Item S. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in 4c above.
•
Item T. Calculate your emission reductions (metric tons CO2e) by subtracting Item R from
Item S, and multiplying the result by Item P.
5. Calculate Carbon Dioxide Displaced by Methane Supplied to a Natural Gas Distribution
Network.
•
Item U. Enter the average annual quantity of methane supplied to a natural gas distribution
network in the Base Period in MMBtu.
•
Item V. Enter the quantity of methane supplied to a natural gas distribution network in the
Reporting Year in MMBtu.
•
Item W. Calculate the incremental quantity of methane supplied to a natural gas distribution
network by subtracting Item U from Item V. Enter the result in Item W, Column 3.
•
Item X. Enter the emissions factor for natural gas from Appendix H.
•
Item Y. Calculate the CO2 emissions displaced by methane supplied to a natural gas
distribution network by multiplying Item W by Item X. Enter the result under Item Y,
Column 3.
6. Calculate Changes in Nitrous Oxide Emissions From Use of Anaerobic Digester.
•
Item Z. Enter Base Period average annual nitrous oxide emissions value (metric tons CO2e)
from Part B, Question 5, Column 6.
•
Item AA. Enter Reporting Year quantity of nitrous oxide emissions value (metric tons CO2e)
from Part B, Question 5, Column 7.
•
Item BB. Calculate and enter the change in nitrous oxide emissions (metric tons CO2e) by
subtracting Item Z from Item AA.
7. Summarize Emissions Reductions.
•
July 29, 2010
Item CC. In the Direct and TOTAL columns (Columns 3 and 6), enter the increase in the
methane captured value (metric tons CO2e) from Item C.
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
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Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item DD. In the Avoided and TOTAL columns (Columns 5 and 6), enter the carbon dioxide
displaced from electricity used onsite (metric tons CO2e) from Item M.
•
Item EE. In the Avoided and TOTAL columns (Columns 5 and 6), enter the carbon dioxide
displaced from electricity sales (metric tons CO2e) from Item T.
•
Item FF. In the Indirect and TOTAL Columns (Columns 4 and 6), enter the carbon dioxide
emissions displaced by methane supplied to a natural gas distribution network from Item Y.
•
Item GG. In the Direct and TOTAL columns (Columns 3 and 6), enter the change in nitrous
oxide emissions value (metric tons CO2e) from Item BB.
•
Item HH. Calculate the net change in emissions by adding the values in the TOTAL Column
for Items CC, DD, EE, and FF, and subtracting the value in the TOTAL Column for Item GG
from the sum. Enter the result under Item HH in the TOTAL column.
8. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
9. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
10. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 7, above to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b))
Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and enter the
quantity of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
97
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B11. Anaerobic Digestion of Animal Waste
Complete Addendum B11 when using the action-specific method for calculating emission reductions
from the capture of methane from anaerobic digestion of animal waste as described in 2.4.5.6.4 of the
Technical Guidelines pursuant to §300.8(h)(5) of 10 CFR Part 300 Guidelines for Voluntary Greenhouse
Gas Reporting.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Enter Location of Livestock Management Facilities. Enter the name and location of each facility
where methane capture occurred.
2. Date Anaerobic Digester Use Began. Enter the month and year the action was initiated. This is the
earliest date when a facility listed in Part A, Question 1 began capturing methane.
3. Describe Action. Describe the action taken in the space provided, explaining its basic nature and
general characteristics, and the manner in which it reduced emissions. Include all information
important to understanding the action and it effects on emissions, as well as any special conditions
necessary to replicate its achievements.
4. Was the Action Reported Last Year? Indicate “Yes” if you included this action (for any of the
facilities listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not include the
action(s) in last year’s report, or you did not file a Form EIA-1605 report last year, indicate “No.”
Part B. Action Quantification
1. Enter Action Characteristics. For each livestock management facility reported in Part A, Question
1, enter each species of animal producing waste handled by the facility that captured methane, and the
corresponding number of animals per species. If one facility includes more than one animal species,
report separate species in separate rows, repeating the name of the facility.
Part C. Emission Reductions
1. Calculate Carbon Dioxide Displaced by Methane Supplied to a Natural Gas Distribution
Network.
•
Item A. Enter the average amount methane supplied annually to a natural gas distribution
network in the Base Period in MMBtu.
•
Item B. Enter the average amount of methane supplied to a natural gas distribution network in the
Reporting Year in MMBtu.
•
Item C. Calculate and enter the incremental amount of methane supplied to a natural gas
distribution network in the Reporting Year in MMBtu (B – A).
•
Item D. Enter the emissions factor for natural gas from Appendix H.
July 29, 2010
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U.S. Department of Energy
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Form EIA-1605
•
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Item E. Calculate and enter the change in carbon dioxide emissions displaced by methane
supplied to a natural gas distribution network.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and enter the amount
of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
99
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B12. Recycling of Fly Ash
Complete Addendum B12 when using the action-specific method for calculating emission reductions
associated with recycling of fly ash as described in 2.4.5.6.7 of the Technical Guidelines pursuant to
Section 300.8(h)(5) of the General Guidelines.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Enter Name and Location of Concrete Manufacturing Facilities Where Fly Ash Was Recycled.
Enter the name and location of each facility where action occurred.
2. Enter Date Fly Ash Recycling Began. Enter the month and year the action was initiated. This is the
earliest date when a facility listed in Part A, Question 1 began recycling fly ash.
3. Describe Action. Describe the action taken in the space provided, explaining its basic nature and
general characteristics, and the manner in which it reduced emissions. Include all information
important to understanding the action and it effects on emissions, as well as any special conditions
necessary to replicate its achievements.
4. Was the Action Reported Last Year? Indicate “Yes” if you included this action (for any of the
facilities listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not include the
action in last year’s report, or you did not file a Form EIA-1605 report last year, indicate “No.”
Part B. Action Quantification
1. Enter Total Quantity of Fly Ash Used and Portland Cement Displaced for Base Period and
Reporting Year.
•
•
Item A. Enter the total quantity of fly ash used in place of Portland cement in each year of your
Base Period (A3-A6) and the total quantity used in the Reporting Year (A8), expressed in metric
tons. Calculate and enter the average quantity of fly ash used per year over the Base Period and
enter the result in Item A7.
Item B. Enter the total quantity of Portland cement displaced by fly ash in each year of your Base
Period in Items B3-B6 and the total quantity displaced in the Reporting Year in Item B8.
Calculate the average quantity of Portland cement displaced per year in the Base Period and enter
the result in Item B7.
2. Calculate Substitution Ratio of Fly Ash for Portland Cement for Base Period and Reporting
Year.
•
Item C. Calculate and enter the Base Period substitution ratio by dividing Item B7 by Item A7.
•
Item D. Calculate and enter the Reporting Year substitution ratio by dividing Item B8 by Item
A8.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Part C. Emission Reductions
1. Calculate Reduction in Indirect Emissions
•
Item E. Enter the net emissions factor for virgin cement (0.2396 metric tons carbon equivalent).
•
Item F. Enter the net emissions factor for fly ash (0.0021 metric tons carbon equivalent).
•
Item G. Enter the conversion factor for carbon equivalent to CO2e (3.667).
•
Item H. Calculate emissions displaced in the Base Period using the following equation:
Item A7 * [(Item E / Item C) - Item F] * Item G.
•
Item I. Calculate emissions displaced in the Reporting Year using the following equation: Item
Item A8 * [(Item E / Item D) - Item F] * Item G.
•
Item J. Calculate and enter the indirect reductions from recycling fly ash by subtracting Item H
from Item I.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emission
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part D. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part D if you have distributed the reductions reported by the entity or subentity in Part C,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the Name of the Recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and enter the amount
of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
101
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B13. Demand-Side Management and Other Emission Reduction
Programs
Complete Addendum B13 when using the action-specific method for calculating emission reductions
associated with demand-side management or other emission reduction programs as described in 2.4.5.6.9
of the Technical Guidelines pursuant to Section 300.8(h)(5) of the General Guidelines.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
If you are reporting more than one program, copy Part A and complete for each program.
1. Enter Name of Program. Enter the name of the demand-side management program.
2. Describe the Program. Describe the action taken in the space provided, explaining its basic nature
and general characteristics, and the manner in which it reduced emissions. Include all information
important to understanding the action and it effects on emissions, as well as any special conditions
necessary to replicate its achievements.
3. Enter all of the following information for the program listed above. Use Column 2 to answer
items A-L.
•
Item A. Enter City of Program. Enter the city in which the program occurs.
•
Item B. Enter State of Program (if domestic). If the program is domestic, enter the state in
which it occurs.
•
Item C. Enter Country of Program (if foreign). If the program is foreign, enter the country in
which it occurs.
•
Item D. Enter Month Program Began. Enter the month in which the program was initiated.
•
Item E. Enter Year Program Began. Enter the year in which the program was initiated.
•
Item F. Describe Program Evaluation Method. Method must be capable of reliably
distinguishing between program effects and non-program-related effects, and capable of
estimating how program-related effects are likely to diminish over time, and may include
statistically valid surveys or energy-use metering.
•
Item G. Enter Name of 3rd Party Verifier. Enter the name of the third-party verifier.
•
Item H. Enter Qualifications of 3rd Party Verifier. To be qualified, the third-party must have
experience in conducting or assessing statistically valid program impact evaluations recognized
by government agencies.
•
Item I. Enter Unit of Annual Energy Usage Reductions in RY. If emission reductions were
not related to energy usage, skip to Part A, Question 2, Item L. Otherwise, enter the quantity of
the energy use reduction.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
•
Item J. Enter Quantity of Annual Energy Usage Reductions in RY. If emission reductions
were not related to energy usage, skip to Part A, Question 2, Item L. Otherwise, enter the unit
used to measure energy consumption (e.g., KWh, MMBtu).
•
Item K. Enter Greenhouse Gas Emission Reductions in RY. Enter Reporting Year emission
reductions for the program.
•
Item L. Do the Reductions Qualify for Registration. To register reductions, the DSM or other
program must meet all of the following criteria:
•
•
•
•
The DSM or other program must be funded by the reporting entity.
The estimated effects reported must first occur after the entity’s start year and must cause a
reduction of the total emissions of residential or other very small emitters.
The qualifying program must provide information or other technical assistance, financial
incentives, direct installation or investment, or other non-commercial services to very small
emitters to assist them achieving emission reductions recognized by these guidelines.
Program evaluations must be performed and/or certified by an independent third party and
qualified third party verifier. The third party must certify that the estimated annual energy
usage or emission reductions were estimated in accordance with these guidelines. Check the
box for “Yes” if the reductions achieved by the program meet all of the criteria listed for
registration. If not, check “No.”
4. Indicate What the Program Provides to Very Small Emitters (entities that typically emit below
500 tons of CO2e per year). Check the box for “Yes” or “No” for each Column 1-4.
5. Identify Sector(s) of Very Small Emitters Targeted. Check the box for “Yes” or “No” for each
Column 1-3. If the answer to Column 4 is “Yes” please provide the specific sector.
Part B. Emissions Reductions
1. Summarize Energy Savings and Greenhouse Gas Emissions Reductions by Program. For each
program enter the program name as reported in Part A, Question 1, and enter the energy unit in
Column 2 (e.g., kWh of electricity, thousand cubic feet of natural gas), the total quantity of energy
savings in Column 3, the emissions unit in Column 4 (e.g., metric tons), and the total quantity of
emission reductions in Column 5. In Column 4 of the bottom row, enter the unit of emission
reductions. In Column 5 of the bottom row, sum the total emission reductions from all programs.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
July 29, 2010
Voluntary Reporting of Greenhouse Gases
103
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the recipient receiving the reduction in Column 1,
enter the units in which the reduction is denominated (metric tons) in Column 3, and enter the
quantity of the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide
equivalent; therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
104
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B14. Combined Heat and Power
Complete Addendum B14 when using the action-specific method for calculating emission reductions
from combined heat and power (CHP) generators as described in 2.4.6.3 of the Technical Guidelines
pursuant to §300.8(h)(5) of the General Guidelines.
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Quantification
1. Enter Plant Emissions Data.
•
Item A. Calculate total CHP plant fuel use by summing the quantities for each year in the Base
Period and dividing by the number of years in the Base Period. Enter the result in Column 3.
•
Item B. Calculate and sum emissions resulting from plant fuel use in each year of the Base Period
using the methods in Chapter 1, Part C of the Technical Guidelines. Divide total Base Period
emissions by the number of years in the Base Period and enter the result in Column 3
•
Item C. Calculate total CHP plant fuel use in the Reporting Year and enter the result in Column
3.
•
Item D. Calculate the emissions resulting from plant fuel use in the Reporting Year using the
methods in Chapter 1, Part C of the Technical Guidelines and enter the result in Column 3.
2. Activity Data.
a. Select Geographic Scope of the Avoided Emissions Benchmark(s) (based on the regions in
Appendix F). Select the appropriate geographic scope from the following: “Single Domestic
Region,” “Multiple Domestic Regions,” and “Foreign Region(s).” The regions must be the statebased regions identified in Appendix F of these instructions.
b. If Reporting Reductions for a Single Domestic Region, Enter the Number of the Region
from Appendix F. If you will be using an avoided emissions benchmark associated with a single
domestic region (and not a weighted benchmark), enter the number of the region from Appendix
F here. Skip to Question 2c if you will need to use multiple regional benchmarks to calculate your
reductions or if the reductions in the addendum apply to foreign sources. As in Question 2a, the
regions must be the state-based regions identified in Appendix F of these instructions.
c. If Reporting Reductions for Multiple or Foreign Regions, Enter the Weighted Avoided
Emissions Benchmark(s) and Briefly Explain How it was Calculated. Enter the appropriately
weighted domestic or foreign electricity and/or thermal avoided emissions benchmark here. You
will need to enter a thermal factor if you are reporting avoided emissions from foreign chilled
water generation. If you are producing chilled water from both electric and natural gas chillers,
enter a weighted thermal factor. Explain how this benchmark was calculated and identify the
regions or countries to which it applies. See Appendix N for guidance on determining
benchmarks for purchased thermal energy.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
d. Enter Activity Data. For Items E through J, enter the specified quantity for the Base Period
average. To calculate the Base Period average, sum the quantities for each year in the Base Period
and divide by the number of years in the Base Period.
•
Item E. Enter the Base Period average total thermal generation for the CHP plant in MMBtu.
•
Item F. Enter the Base Period average total electrical generation for the CHP plant in MWh.
•
Item G. Enter the Base Period average amount of thermal energy exported for use by other
entities in MMBtu.
•
Item H. Enter the Base Period average amount of electricity exported for use by other entities
in MWh.
•
Item I. Enter the Base Period average thermal generating efficiency for the CHP plant. If this
efficiency is not known, use a default value of 80 percent.
•
Item J. Enter the Base Period average electrical generating efficiency for the CHP plant. If
this efficiency is not known, use a default value of 35 percent.
•
Item K. Enter the total thermal generation for the CHP plant in the Reporting Year in
MMBtu.
•
Item L. Enter the total electrical generation for the CHP plant in the Reporting Year in MWh.
•
Item M. Enter the amount of thermal energy exported for use by other entities in the
Reporting Year in MMBtu.
•
Item N. Enter the amount of electricity exported for use by other entities in the Reporting
Year in MWh.
•
Item O. Enter the thermal generating efficiency for the CHP plant in the Reporting Year. If
this efficiency is not known, use a default value of 80 percent.
•
Item P. Enter the electrical generating efficiency for the CHP plant in the Reporting Year. If
this efficiency is not known, use a default value of 35 percent.
•
Item Q. Enter the applicable thermal Avoided Emissions Benchmark, which may be found in
Appendix N. If chilled water for multiple regions is included, copy the weighted benchmark
from 2c above.
•
Item R. Enter the applicable Avoided Emissions Benchmark for electricity from Appendix F
(for a single U.S. region) or the weighted/foreign benchmark as entered in 2c above.
3. Calculate Emissions for Each Generating Stream. Calculate and enter emissions for each
generating stream expressed in metric tons CO2e as follows:
•
Item S. Calculate and total thermal generation emissions for the Base Period using the following
equation:
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Item B * {(Item E / Item I) / [(Item E / Item I) + (Item F / Item J)]}.
•
Item T. Calculate total electricity generation emissions for the Base Period by subtracting Item S
from Item B.
•
Item U. Calculate and total thermal generation emissions for the Reporting Year using the
following equation:
Item D * {(Item K / Item O) / [(Item K / Item O) + (Item L / Item P)]}.
•
Item V. Calculate total electricity generation emissions for the Reporting Year by subtracting
Item U from Item D.
4. Calculate Emissions Associated With Thermal and Electrical Energy Exported and Used
Onsite.
•
Item W. Calculate and enter the exported thermal generation emissions for the Base Period
(metric tons CO2e) by dividing the thermal exports Base Period average (as entered in Item G) by
the total thermal generation Base Period average (as entered in item E), and multiplying the result
by the total thermal generation emissions for the Base Period (as entered in Item S).
•
Item X. Calculate and enter the exported electrical generation emissions for the Base Period
(metric tons CO2e) by dividing the electricity exports Base Period average (as entered in Item H)
by the total electrical generation Base Period average (as entered in Item F), and multiplying the
result by the total electricity generation emissions for the Base Period (as entered in item T).
•
Item Y. Calculate and enter the onsite thermal generation emissions for the Base Period (metric
tons CO2e) by subtracting the value entered for Item W, above, from the total thermal generation
emissions for the Base Period (as entered in Item S).
•
Item Z. Calculate and enter the onsite electrical generation emissions for the Base Period (metric
tons CO2e) by subtracting the value entered for Item X, above, from the total electricity
generation emissions for the Base Period (as entered in Item T).
•
Item AA. Calculate and enter the exported thermal generation emissions for the Reporting Year
by dividing the thermal exports for the Reporting Year (as entered in Item M) by the total thermal
generation for the Reporting Year (as entered in Item K), and multiplying the result by the total
thermal generation emissions for the Reporting Year (as entered in Item U).
•
Item BB. Calculate and enter the exported electrical generation emissions for the Reporting Year
by dividing the electricity exports for the Reporting Year (as entered in Item N) by the total
electrical generation for the Reporting Year (as entered in Item L), and multiplying the result by
the total electricity generation emissions for the Reporting Year (as entered in Item V).
•
Item CC. Calculate and enter the onsite thermal generation emissions for the Reporting Year
(metric tons CO2e) by subtracting the value entered for Item AA, above, from the total thermal
generation emissions for the Reporting Year (as entered in Item U).
•
Item DD. Calculate and enter the onsite electrical generation emissions for the Reporting Year
(metric tons CO2e) by subtracting the value entered for Item BB, above, from the total electricity
generation emissions for the Reporting Year (as entered in Item V).
July 29, 2010
Voluntary Reporting of Greenhouse Gases
107
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Part B. Emission Reductions
1. Calculate Direct Emission Reductions From Onsite Energy Use. Use the method in Question 1a,
below, if you are using the emissions intensity method to calculate onsite emission reductions. If
using absolute emissions reduction method to calculate onsite emission reductions, use the method in
Question 1b, below.
a. Calculate Changes in Emissions Intensity From Energy Used Onsite. (Use this method if you
are using emissions intensity method to calculate onsite emission reductions).
•
Item EE. Calculate and enter the direct emission reductions from thermal generation used
onsite (metric tons CO2e) by calculating the difference between Item S divided by Item E and
Item U divided by Item K, and multiplying the result by the difference between Item K and
Item M.
•
Item FF. Calculate and enter the direct emission reductions from electrical generation used
onsite (metric tons CO2e) by calculating the difference between Item T divided by Item F and
Item V divided by Item L, and multiplying the result by the difference between Item L and
Item N.
b. Calculate Absolute Changes in Emissions From Energy Used Onsite. (Use this method if you
are using absolute emissions method to calculate onsite emission reductions).
•
Item GG. Calculate and enter the emission reductions from thermal generation used onsite
(metric tons CO2e) by subtracting the onsite thermal generation emissions for the Reporting
Year (as entered for Item CC above) from the onsite thermal generation emissions for the
Base Year (as entered for Item Y above).
•
Item HH. Calculate and enter the emission reductions from electrical generation used onsite
(metric tons CO2e) by subtracting the onsite electrical generation emissions for the Reporting
Year (as entered for Item DD above) from the onsite electrical generation emissions for the
Base Year (as entered for Item Z above).
2. Calculate Emission Reductions Associated With Energy Exports
a. Calculate the Thermal Energy Emission Reductions Due to Improvements in Historical
Emissions Intensity. To calculate Item II expressed in metric tons CO2e, subtract the result of
Item U divided by Item K from the result of Item S divided by Item E, and multiply the result by
Item G.
b. Calculate Thermal Energy Emission Reductions Due to Incremental Changes in Thermal
Exports. To calculate Item JJ expressed in metric tons CO2e, subtract the result of Item U divided
by Item K from Item Q, and multiply the result by the result of Item M minus Item G.
c. Calculate Electricity Emission Reductions Due to Improvements in Historical Emissions
Intensity. To calculate Item KK expressed in metric tons CO2e, subtract the result of Item V
divided by Item L from the result of Item T divided by Item F, and multiply the result by Item H.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
d. Calculate and Enter the Electricity Emission Reductions Due to Incremental Changes in
Electricity Exports. To calculate Item LL expressed in metric tons CO2e, subtract the result of
Item V divided by Item L from Item R, and then multiply by the result of Item N minus Item H.
3. Summarize Emission Reductions
•
Item MM. Calculate and enter the reductions associated with onsite energy use, expressed in
metric tons CO2e, which is the sum of Item EE and Item FF, if using the Changes in Emissions
Intensity method, or the sum of Item GG and HH, if using the Changes in Absolute Emissions
method.
•
Item NN. Calculate and enter the total emission reductions from energy generation and exports,
expressed in metric tons CO2e, by summing Items II, JJ, KK, and LL.
•
Item OO. Sum and enter the total emission reductions, expressed in metric tons CO2e, by adding
the reductions associated with onsite energy use (as calculated in MM) and the total emission
reductions from energy generation and exports (as calculated in NN).
4. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
5. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement and “Local requirement.”
6. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 3 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the entity receiving the reduction in Column 1, enter
the units in which the reduction is denominated (metric tons) in Column 3, and enter the quantity of
the reduction in Column 4. The reduction distributed must be recorded in carbon dioxide equivalent;
therefore, CO2e has been printed in Column 2.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
109
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B15. Other Action-Specific Methods
Complete Addendum B15 if you intend to calculate emission reductions using the generic, other actionspecific method. Note that this method can only be used if it is not possible to use any of the other
emission reduction methods contained in Addendum B (B1 – B14).
If you are reporting reductions for a subentity, enter the name of the subentity in the space provided.
Part A. Action Identification
1. Explain Why It Is Not Possible To Use Any of the Methods in Addendum B1-B14. Provide an
explanation in the space provided of why none of the other emission reduction methods (embodied in
Addenda B1 through B14) could be used to estimate reductions for your entity or subentity.
2. Enter Date Action Was Initiated. Enter the month and year when the action was initiated.
3. Was the Action Reported Last Year? Indicate whether you have submitted information on this
action in a previous Reporting Year by checking the “Yes” or “No” checkbox.
4. Identify Activities Affected by the Action. Identify the activities that were affected by the action
and provide specific information on the technology, process, or output involved.
5. Identify Equipment Affected by the Action. Identify and quantify any equipment that was affected
by the action. For example, the reporter should provide the number of vehicles, transformers, or lights
affected by the action.
6. Identify the Emission Sources Affected by the Action. Identify the emission sources that were
affected by the action.
Part B. Emission Reduction Computation
1. Enter Activity Data, Emission Coefficients, and Conversion Factors. Enter any activity data,
emission coefficients, and conversion factors that you used to estimate the emission reduction for
your action. For example, an entity conducting an motor efficiency effort would report the following
information:
•
Item A. Base Period average annual electricity consumption by motors in kWh.
•
Item B. Reporting Year electricity consumption by motors in kWh.
•
Item C. Applicable regional electricity end-use emission coefficient in metric tons CO2 per
MWh.
2. Enter Equation(s) Used To Calculate Base Period and Reporting Year Emissions in Question 3.
Using the item designations for the information entered in Question 1, enter the equations used to
calculate the reduction. For the above example, the equation would be written as follows:
Base Period Emissions = A * (1 MWh / 1000 kWh) * C
Reporting Year Emissions = B * (1 MWh / 1000 kWh) * C
July 29, 2010
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
3. Calculate Emission Reductions. Calculate and enter emissions and emission reductions for the
following sources of emissions affected by the action: direct (Column 3), indirect from purchased
energy (Column 4), and other indirect (Column 5). Calculate and enter the following:
•
Item K. Base Period Emissions. Calculate and enter the average annual emissions associated
with the action during the Base Period.
•
Item L. Reporting Year Emissions. Calculate and enter the emissions associated with the action
during the Reporting Year.
•
Item M. Registered Emission Reductions. If you intend to register emission reductions,
calculate and enter the reductions of direct emissions (Column 3) and indirect emissions from
purchased energy (Column 4) by subtracting Reporting Year emissions (Item L) from Base
Period emissions (Item K). (Note that reductions of other indirect emissions may not be registered
and must be entered under Item N.)
•
Item N. Reported Emission Reductions If you intend to report emission reductions, calculate
and enter the reductions of direct emissions (Column 3), indirect emissions from purchased
energy (Column 4), and other indirect emissions (Column 5) by subtracting Reporting Year
emissions (Item L) from the corresponding Base Period emissions value (Item K).
4. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
5. Identify the Cause(s) of the Emission Reduction(s). Check the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting for a foreign subentity and the reductions were caused by a
requirement of a foreign government, check “Government requirement” and “Local requirement.”
6. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 3 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the entity receiving the reduction in Column 1, enter
the emission reduction type (Direct, Indirect, or Other Indirect) in Column 2, enter the units in which
the reduction is denominated (metric tons) in Column 4, and enter the quantity of the reduction in
Column 5. The reduction distributed must be recorded in carbon dioxide equivalent; therefore, CO2e
has been printed in Column 3. Sum the total direct, indirect, or other indirect reductions and enter
these amounts in the specified “Total” rows.
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U.S. Department of Energy
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
B16. Destruction of Chlorofluorocarbons
Complete Addendum B16 when using the action-specific method for calculating emission reductions
associated with destruction of chlorofluorocarbons (CFCs) as described in 2.4.5.6.8 of the Technical
Guidelines pursuant to Section 300.8(h)(5) of the General Guidelines. Reporters may report but not
register reductions associated with the destruction of CFCs.
If you are reporting but not registering reductions for a subentity, enter the name of the subentity in the
space provided.
Part A. Action Identification
1. Enter Name and Location of Facility Where CFCs Were Destroyed. Enter the name and location
of each facility where action occurred.
2. Enter Date CFC Destruction Began. Enter the month and year the action was initiated. This is the
earliest date when a facility listed in Part A, Question 1 began destroying CFCs.
3. Describe Action. Describe the action taken in the space provided, explaining its basic nature, general
characteristics, and the manner in which it reduced emissions. Include all information important to
understanding the action and it effects on emissions, as well as any special conditions necessary to
replicate its achievements.
4. Was the Action Reported Last Year? Indicate “Yes” if you included this action (for any of the
facilities listed in Part A, Question 1) on last year’s Form EIA-1605 report. If you did not include the
action in last year’s report, or you did not file a Form EIA-1605 report last year, indicate “No.”
Part B. Emission Reductions
1. Enter Type and Quantity of CFCs Destroyed. In Column 1, indicate the type of CFC destroyed. In
Column 2, report the unit of measure expressed as kilograms or metric tons. In column 3, enter the
quantity of each type of CFC destroyed. In Column 4, indicate whether the reduction was transferred
to another reporting entity. If “Yes,” complete Part C.
2. Identify and Describe the Types of Actions That Were the Likely Causes of the Reductions
Achieved. Enter the code for each action that was a likely cause of the emission reduction (see action
type codes in Appendix M). Use the space provided to describe each action briefly.
3. Identify the Cause(s) of the Emission Reduction(s). Select the applicable check boxes
corresponding to the causes of the emission reductions achieved by your entity or subentity. If the
reduction is the result of a government requirement, check the applicable requirement types (Federal,
State and/or Local). If you are reporting but not registering for a foreign subentity and the reductions
were caused by a requirement of a foreign government, check “Government requirement and “Local
requirement.”
4. Summarize Benefits and Costs of the Actions Taken To Reduce Greenhouse Gas Emissions
(Optional). Reporters may use the space provided to record information on the benefits and costs of
the actions taken to reduce emissions, such as the expected rates of return, life cycle costs, or benefit
to cost ratios, using appropriate discount rates.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
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U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Part C. Distribution of Emission Reductions to Other 1605(b) Reporters
Complete Part C if you have distributed the reductions reported by the entity or subentity in Part B,
Question 1 to another reporter to the Voluntary Reporting of Greenhouse Gases (1605(b)) Program.
1. Where Applicable, Enter Emission Reductions Distributed to Other 1605(b) Reporters. For each
emission reduction distributed, enter the name of the entity receiving the reduction in Column 1, enter
the native gas in Column 2, enter the units in which the reduction is denominated (metric tons or
kilograms) in Column 3, and enter the quantity of the reduction in Column 4.
July 29, 2010
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for Addendum C, Country-Specific Factors Used
To Estimate Emissions From Foreign Sources
Complete Addendum C if you are reporting emissions for a foreign subentity.
1. Enter Information on Emission Factors Used To Estimate Emissions for Foreign Subentities.
Enter the following information for each emission factor used in estimating emissions for a foreign
subentity:
a. Emissions Type (Column 1). Enter the emission type (e.g., Direct, Indirect from Purchased
Energy, Other Indirect, Terrestrial Carbon Flux and Stocks).
b. Emission Source (Column 2). Enter the emission source for which the factor was used using the
codes listed in Appendix J.
c. Gas (Column 3). Identify the gas for which the factor is applicable.
d. Unit of Measure (Column 4). Enter the unit of measure for the factor (e.g., metric tons of gas
per MMBtu).
e. Factor Value (Column 5). Enter the quantitative value of the factor.
f.
Countries/Regions (Column 6). List the countries or regions for which you have used the
emission factor. For countries, use the country codes in Appendix C.
g. Factor Source (Column 7). Use the Item letter in the left hand column of the table in Question 2
to identify the source of the emission factor (e.g., publication, Web site) listed. If there is no
publically available documentation for the emission factor, enter “T” and describe how this factor
was developed in Question 3.
2. Identify the Publications and Other Sources for Factors Used To Estimate Foreign Emissions.
List the publications and other reference that were the sources for the emission factors used in
preparing the emissions inventory for any foreign subentity included in your report.
3. Document Reporter-Defined Emission Factors. For emission factors that do not have publicly
available documentation exists or to which you have made adjustments, describe how these factors
were developed or adjusted in the space provided below.
July 29, 2010
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Instructions for Addendum D, Non-Reporter Offset Entity
Information
Only reporters who are receiving offsets from a non-reporter to the Voluntary Reporting of Greenhouse
Gases Program must complete Sections 1, 2 and 3 of Addendum D. You do not need to complete
Addendum D if this is a Start Year report.
Section 1. Offset Entity Statement
1. Enter Offset Entity Identification. Please provide the entity’s legal name and complete address. In
addition, include a website and/or a Tax Payer Identification Number if applicable.
2. Enter Offset Contact Information. Provide the name and complete contact information, including
title, address, telephone number, fax, and email address, of a person who can answer questions
regarding the content of the submitted form. If the contact person’s address is identical to the entity’s
address, please check the relevant box, and leave the Address, City, State, and Zip lines blank. Enter
the phone number, fax, and e-mail address for the contact.
3. Enter Entity Type (check one): Indicate by checking the appropriate box whether the entity is one
of the following: “Large Emitter (more than 10,000 metric tons carbon dioxide equivalent annually)”
or “Small Emitter (less than 10,000 metric tons carbon dioxide equivalent annually).”
4. Indicate Any Significant Changes to Previous Entity Statement. Complete this question if this is a
Reporting Year report. Check one of the following: “The entity has not undergone significant changes
since the last Voluntary Reporting of Greenhouse Gases report,” or “The entity has undergone
significant changes since the last Voluntary Reporting of Greenhouse Gases report.” Describe any
significant changes the entity has undergone since the previous year’s report. Check the applicable
boxes and provide descriptive information where requested.
5. Identify the Entity’s Primary Economic Activities. Enter the primary (and, if applicable, the
secondary) 3-digit North American Industrial Classification System (NAICS) code for the entity. (For
a list of NAICS codes, see Appendix A.)
6. Enter the Entity Category. Check the applicable boxes to describe the entity. If none of the listed
categories applies to the entity, check “Other” and briefly describe the nature of the entity in the space
provided.
7. Describe the Entity Organization. Use the check box to indicate whether the entity is a holding
company, and if not, enter the name of the entity's Parent or Holding Company if applicable.
8. Describe the Entity’s Organizational Boundaries. Use questions 8a through 8d to define the
organizational boundaries of the entity and to indicate which method was used to draw these
boundaries.
a. Method for Determining Organizational Boundaries. Check the box to indicate your method
for defining the organizational boundaries of the entity. As discussed in the General
Guidelines, the primary basis for defining organizational boundaries should be financial
control, although entities retain the flexibility to use other approaches, such as equity share or
operational control if necessary. For all boundary definition approaches except financial
control, please provide an explanation of the approach. If the entity chooses to use an
approach other than financial control, equity share, or operational control, please check the
“Other” box, list the other method where indicated, and describe how the use of this other
approach results in organizational boundaries that differ from those resulting from using the
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Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
financial control approach. Definitions for these Organizational Boundary terms can be found
in the Glossary of Selected Terms.
b. List All Large Wholly Owned Subsidiaries. List all large wholly owned subsidiaries included
in this report, by name and NAICS code. (For a list of NAICS codes, see Appendix A.)
c. List Any Large Partially Owned Subsidiaries, Joint Ventures, and Leased or Operated
Sources. For any large partially owned subsidiary, joint venture, and leased or operated
emissions source included in your report, provide the following information:
•
•
•
•
•
Name or Description of Emissions Source;
Relationship to Entity (subsidiary, joint venture, leased, operated under contract,
other);
Partners, Percent Interest Held by Entity;
Method for Determining Inclusion in Report (financial control, equity share,
operational control, other); and
Percentage of Emissions Included in This Report.
d. Additional Description of Organizational Boundaries. Provide any additional description of
organizational boundaries, including criteria used for excluding any emissions sources, if
applicable (pursuant to §300.5(d)(3)(ii) of 10 CFR Part 300, General Guidelines for
Voluntary Greenhouse Gases Reporting).
9. Describe the Geographic Scope of Activities: Check the appropriate box to indicate whether this
report covers only U.S. activities or U.S. and non-U.S. activities. In either case, please also check the
applicable box regarding the scope of the entity’s activities in the U.S. using the following criteria:
Nationwide: Check the box for Nationwide if the entity has operations in at least one state in
each of the 9 U.S. Census Divisions. The U.S. Census Divisions are identified in Appendix B.
Multiple States: Check the box for Multiple States if the entity has operations in more than one
State but does not meet the criteria for Nationwide. List the States in which the entity has
operations using the two-letter abbreviations listed in Appendix B.
Single State: Check the box for Single State if the entity has operations in only one State.
Identify the state in the space provided using the two-letter abbreviations listed in Appendix B.
If this report covers U.S. and Non-U.S. activities, please also list all foreign countries in which
reported activities occurred, and using the 3-digit codes found in Appendix C, enter the NAICS code
that best corresponds to the primary activity of the operations in each country.
10. Describe the Scope of Emissions Inventory: If your report includes an emissions inventory, check
the applicable box for each of the emissions sources included.
11. Describe the Entity Base Period: Check the box indicating the number of years in the Base Period,
and enter the last year in Base Period. The Base Period for the offset provider may be different from
the reporting entity.
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Section 2. Offset Entity Emissions Inventory
Part A. Aggregated Emissions by Gas (for independently verified reports only)
If the reporting entity’s report submitted is independently verified, that entity may complete only Part A,
Aggregated Emissions by Gas, on behalf of the offset provider. Copy and attach one copy of Part A from
Addendum A.
Part B. Inventory of Emissions and Carbon Flux (optional for independently
verified reports)
If the reporting entity’s report submitted is not independently verified, they must complete Part B,
Inventory of Emissions and Carbon Flux, on behalf of the offset provider. Copy and attach one copy of
Part B from Addendum A.
Section 3. Offset Entity-Level Reduction Methods and Reductions
All entities that are reporting offsets from a non-reporter must complete the appropriate addendum
(Addendum B1-B16) for each offset obtained.
1. Indicate the method used to estimate entity-wide emission reductions by checking the appropriate
checkbox.
2. If the entity who is receiving offsets from a non-reporting offset provider is registering their emission
reductions and the offsets are being estimated using the Changes in Emissions Intensity (Addendum
B1) or Energy Generation and Distribution (Addendum B5) methods, indicate whether or not the nonreporting offset provider is reporting but not registering reductions calculated using the Changes in
Absolute Emissions (Addendum B2) method. The reporter may choose to supplement the entity
statement completed on behalf of the offset provider using an intensity-based method with a report of
reduction in absolute emissions even if the output of the entity is declining. The reductions in absolute
emissions included in this supplemental report are not eligible for registration.
3. Complete and attach the emission reduction addendum(s) (Addendum B1-B16) indicated in Question
1 that was used to estimate reductions domestic emissions.
4. If you are reporting non-U.S. emissions within one entity-level report, attach one copy of the
emission reduction addendum (Addendum B1-B16) indicated in Question 1 that was used to estimate
reductions in foreign emissions.
July 29, 2010
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Appendix A. North American Industrial Classification
System (NAICS) Codes
Agriculture, Forestry, Fishing and Hunting
111
Crop Production
112
Animal Production
113
Forestry and Logging
114
Fishing, Hunting and Trapping
115
Support Activities for Agriculture and Forestry
Mining
211
212
213
Oil and Gas Extraction
Mining (except Oil and Gas)
Support Activities for Mining
Utilities
221
Utilities
Construction
236
Construction of Buildings
237
Heavy and Civil Engineering Construction
238
Specialty Trade Contractors
Manufacturing
311
Food Manufacturing
312
Beverage and Tobacco Product Manufacturing
313
Textile Mills
314
Textile Product Mills
315
Apparel Manufacturing
316
Leather and Allied Product Manufacturing
321
Wood Product Manufacturing
322
Paper Manufacturing
323
Printing and Related Support Activities
324
Petroleum and Coal Products Manufacturing
325
Chemical Manufacturing
326
Plastics and Rubber Products Manufacturing
327
Nonmetallic Mineral Product Manufacturing
331
Primary Metal Manufacturing
332
Fabricated Metal Product Manufacturing
333
Machinery Manufacturing
334
Computer and Electronic Product
Manufacturing
335
Electrical Equipment, Appliance, and
Component Manufacturing
336
Transportation Equipment Manufacturing
337
Furniture and Related Product Manufacturing
339
Miscellaneous Manufacturing
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Wholesale Trade
423
Merchant Wholesalers, Durable Goods
424
Merchant Wholesalers, Nondurable Goods
425
Wholesale Electronic Markets and Agents and
Brokers
Retail Trade
441
Motor Vehicle and Parts Dealers
442
Furniture and Home Furnishings Stores
443
Electronics and Appliance Stores
444
Building Material and Garden Equipment and
Supplies Dealers
445
Food and Beverage Stores
446
Health and Personal Care Stores
447
Gasoline Stations
448
Clothing and Clothing Accessories Stores
451
Sporting Goods, Hobby, Book, and Music
Stores
452
General Merchandise Stores
453
Miscellaneous Store Retailers
454
Nonstore Retailers
Transportation and Warehousing
481
Air Transportation
482
Rail Transportation
483
Water Transportation
484
Truck Transportation
485
Transit and Ground Passenger Transportation
486
Pipeline Transportation
487
Scenic and Sightseeing Transportation
488
Support Activities for Transportation
491
Postal Service
492
Couriers and Messengers
493
Warehousing and Storage
Information
511
Publishing Industries (except Internet)
512
Motion Picture and Sound Recording
Industries
515
Broadcasting (except Internet)
516
Internet Publishing and Broadcasting
517
Telecommunications
518
Internet Service Providers, Web Search
Portals, and Data Processing Services
519
Other Information Services
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Finance and Insurance
521
Monetary Authorities - Central Bank
522
Credit Intermediation and Related Activities
523
Securities, Commodity Contracts, and Other
Financial Investments and Related Activities
524
Insurance Carriers and Related Activities
525
Funds, Trusts, and Other Financial Vehicles
Real Estate and Rental and Leasing
531
Real Estate
532
Rental and Leasing Services
533
Lessors of Nonfinancial Intangible Assets
(except Copyrighted Works)
Professional, Scientific, and Technical Services
541
Professional, Scientific, and Technical
Services
Management of Companies and Enterprises
551
Management of Companies and Enterprises
Administrative and Support and Waste Management
and Remediation Services
561
Administrative and Support Services
562
Waste Management and Remediation Services
Educational Services
611
Educational Services
Health Care and Social Assistance
621
Ambulatory Health Care Services
622
Hospitals
623
Nursing and Residential Care Facilities
624
Social Assistance
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Arts, Entertainment, and Recreation
711
Performing Arts, Spectator Sports, and Related
Industries
712
Museums, Historical Sites, and Similar
Institutions
713
Amusement, Gambling, and Recreation
Industries
Accommodation and Food Services
721
Accommodation
722
Food Services and Drinking Places
Other Services (Except Public Administration)
811
Repair and Maintenance
812
Personal and Laundry Services
813
Religious, Grantmaking, Civic, Professional,
and Similar Organizations
814
Private Households
Public Administration
921
Executive, Legislative, and Other General
Government Support
922
Justice, Public Order, and Safety Activities
923
Administration of Human Resource Programs
924
Administration of Environmental Quality
Programs
925
Administration of Housing Programs, Urban
Planning, and Community Development
926
Administration of Economic Programs
927
Space Research and Technology
928
National Security and International Affairs
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Appendix B. U.S. Census Divisions and Abbreviations
for States and U.S. Territories
Source: http://www.eia.doe.gov/emeu/reps/maps/us_census.html.
Census Bureau Regions and Divisions With State Abbreviations
REGION 1: NORTHEAST
REGION 2: MIDWEST*
Division 1: New England
Connecticut
CT
Maine
ME
Massachusetts
MA
New Hampshire
NH
Rhode Island
RI
Vermont
VT
Division 3: East North Central
Illinois
IL
Indiana
IN
Michigan
MI
Ohio
OH
Wisconsin
WI
Division 2: Middle Atlantic
New Jersey
NJ
New York
NY
Pennsylvania
PA
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Division 4: West North Central
Iowa
IA
Kansas
KS
Minnesota
MN
Missouri
MO
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Nebraska
North Dakota
South Dakota
NE
ND
SD
REGION 3: SOUTH
Division 5: South Atlantic
Delaware
DE
District of Columbia
DC
Florida
FL
Georgia
GA
Maryland
MD
North Carolina
NC
South Carolina
SC
Virginia
VA
West Virginia
WV
Division 6: East South Central
Alabama
AL
Kentucky
KY
Mississippi
MS
Tennessee
TN
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Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
REGION 4: WEST
Division 8: Mountain
Arizona
Colorado
Idaho
Montana
Nevada
New Mexico
Utah
Wyoming
AZ
CO
ID
MT
NV
NM
UT
WY
Division 9: Pacific
Alaska
California
Hawaii
Oregon
Washington
AK
CA
HI
OR
WA
Division 7: West South Central
Arkansas
AR
Louisiana
LA
Oklahoma
OK
Texas
TX
*Prior to June 1984, the Midwest Region was designated as the North Central Region.
Source: http://www.census.gov/geo/www/reg_div.txt.
Abbreviations for U.S. Territories
American Samoa
Guam
Midway Islands
Northern Mariana
Islands
Puerto Rico
U.S. Virgin Islands
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AQ
GQ
MQ
CQ
PR
VQ
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OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Appendix C. Country Codes
Code
AF Afghanistan
Country
Code
BU Bulgaria
Country
AL
Albania
UV
Burkina Faso
AG
Algeria
BM
Burma
AN
Andorra
BY
Burundi
AO
Angola
CB
Cambodia
AV
Anguilla
CM Cameroon
AY
Antarctica
CA
Canada
AC
Antigua and Barbuda
CV
Cape Verde
AR
Argentina
CJ
Cayman Islands
AM Armenia
CT
Central African Republic
AA
Aruba
CD
Chad
AT
Ashmore and Cartier Islands
CI
Chile
AS
Australia
CH
China
AU
Austria
KT
Christmas Island
AJ
Azerbaijan
IP
Clipperton Island
BF
Bahamas, The
CK
Cocos (Keeling) Islands
BA
Bahrain
CO Colombia
FQ
Baker Island
CN
Comoros
BG
Bangladesh
CF
Congo
BB
Barbados
CG Congo, Democratic Republic of the
BS
Bassas Da India
CW Cook Islands
BO
Belarus
CR
Coral Sea Islands
BE
Belgium
CS
Costa Rica
BH
Belize
IV
Cote D'ivoire
BN
Benin
HR
Croatia
BD
Bermuda
CU
Cuba
BT
Bhutan
CY
Cyprus
BL
Bolivia
EZ
Czech Republic
BK
Bosnia and Herzegovina
DA
Denmark
BC
Botswana
DJ
Djibouti
BV
Bouvet Island
DO Dominica
BR
Brazil
DR
Dominican Republic
IO
British Indian Ocean Territory
TT
East Timor
VI
British Virgin Islands
EC
Ecuador
BX
Brunei
EG
Egypt
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Code
ES El Salvador
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Expiration Date: TBD
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Country
Code
HK Hong Kong
Country
EK
Equatorial Guinea
HQ Howland Island
ER
Eritrea
HU
Hungary
EN
Estonia
IC
Iceland
ET
Ethiopia
IN
India
EU
Europa Island
ID
Indonesia
FK
Falkland Islands (Islas Malvinas)
IR
Iran
FO
Faroe Islands
IZ
Iraq
FM
Federated States of Micronesia
EI
Ireland
FJ
Fiji
IS
Israel
FI
Finland
IT
Italy
FR
France
JM
Jamaica
FG
French Guiana
JN
Jan Mayen
FP
French Polynesia
JA
Japan
FS
French Southern and Antarctic Lands
DQ Jarvis Island
GB
Gabon
JE
Jersey
GA
Gambia, The
JQ
Johnston Atoll
GZ
Gaza Strip
JO
Jordan
GG Georgia
JU
Juan De Nova Island
GM Germany
KZ
Kazakhstan
GH Ghana
KE
Kenya
GI
KQ
Kingman Reef
GO Glorioso Islands
KR
Kiribati
GR Greece
KN
Korea, Democratic People's Republic of
GL
Greenland
KS
Korea, Republic of
GJ
Grenada
KU
Kuwait
GP
Guadeloupe
KG
Kyrgyzstan
GT
Guatemala
LA
Laos
GK
Guernsey
LG
Latvia
GV
Guinea
LE
Lebanon
PU
Guinea-Bissau
LT
Lesotho
GY
Guyana
LI
Liberia
HA
Haiti
LY
Libya
HM Heard Island and McDonald Islands
LS
Liechtenstein
HO Honduras
LH
Lithuania
Gibraltar
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Code
LU Luxembourg
Country
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Code
NF Norfolk Island
Country
MC Macau
NO Norway
MK Macedonia
MU Oman
MA Madagascar
PK
Pakistan
MI
PS
Palau
MY Malaysia
LQ
Palmyra Atoll
MV Maldives
PM Panama
ML
Mali
PP
Papua New Guinea
MT
Malta
PF
Paracel Islands
IM
Man, Isle of
PA
Paraguay
RM Marshall Islands
PE
Peru
MB Martinique
RP
Philippines
MR Mauritania
PC
Pitcairn Islands
MP Mauritius
PL
Poland
MF
PO
Portugal
MX Mexico
QA
Qatar
MD Moldova
RE
Reunion
MN Monaco
RO Romania
MG Mongolia
RS
MJ
RW Rwanda
Malawi
Mayotte
Montenegro
Russia
MH Montserrat
SC
St. Kitts and Nevis
MO Morocco
SH
St. Helena
MZ
ST
St. Lucia
WA Namibia
SB
St. Pierre and Miquelon
NR
Nauru
VC
St. Vincent and The Grenadines
BQ
Navassa Island
WS Samoa
NP
Nepal
SM
San Marino
NL
Netherlands
TP
Sao Tome and Principe
NT
Netherlands Antilles
SA
Saudi Arabia
NC
New Caledonia
SG
Senegal
NZ
New Zealand
RB
Serbia
NU
Nicaragua
SE
Seychelles
NG Niger
SL
Sierra Leone
NI
Nigeria
SN
Singapore
NE
Niue
LO
Slovakia
Mozambique
July 29, 2010
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Code
SI Slovenia
Form Approved
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Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Country
Code
TE Tromelin Island
Country
BP
Solomon Islands
TS
Tunisia
SO
Somalia
TU
Turkey
SF
South Africa
TX
Turkmenistan
SX
South Georgia and the South Sandwich
Islands
TK
Turks and Caicos Islands
TV
Tuvalu
SP
Spain
UG Uganda
PG
Spratly Islands
UP
Ukraine
CE
Sri Lanka
AE
United Arab Emirates
SU
Sudan
UK
United Kingdom
NS
Suriname
UY
Uruguay
SV
Svalbard
UZ
Uzbekistan
WZ Swaziland
NH
Vanuatu
SW Sweden
VT
Vatican City
SZ
Switzerland
VE
Venezuela
SY
Syria
VM Vietnam
TI
Tajikistan
WQ Wake Island
TZ
Tanzania
WF Wallis and Futuna
TH
Thailand
WE West Bank
TW Taiwan
WI
Western Sahara
TO
Togo
YM
Yemen
TL
Tokelau
ZA
Zambia
TN
Tonga
ZI
Zimbabwe
TD
Trinidad And Tobago
Sources: (1) National Institute of Standards and Technology, Information Technology Laboratory, Federal Information Processing
Standards Publication 10-4, Specifications for Countries, Dependencies, Areas of Special Sovereignty, and Their Principal
Administrative Divisions, 1995 April, http://www.itl.nist.gov/fipspubs/fip10-4.htm.
(2) National Geospatial Intelligence Agency, FIPS 10-4 Change Notices, http://earth-info.nga.mil/gns/html/fips_files.html.
July 29, 2010
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Form Approved
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Expiration Date: TBD
Appendix D. Greenhouse Gas Reduction Initiatives
Domestic Voluntary Initiatives
Code
Program
AGS
AgSTAR
CCP
Cool Communities Program
CCTY
Clean Cities Program
CLL
Climate Leaders
CLV
Climate VISION
CMOP
Coalbed Methane Outreach Program
ESB
Energy Star Buildings and Green Lights Partnership
ESC
Energy Star Computers Program
ESSB
Energy Star Small Business Program
EST
Energy Star Transformers
ESP
Other Energy Star Programs
FSP
Forest Stewardship Program
LMOP
Landfill Methane Outreach Program
NGS
Natural Gas STAR
OTH
Other Federal, state and local programs
RBA
Rebuild America
RGGI
Regional Greenhouse Gas Initiative
RLMP
Ruminant Livestock Methane Program
SFERP Sulfur Hexafluoride (SF6) Emissions Reduction Partnership for Electric Power Systems
VAIP
Voluntary Aluminum Industrial Partnership
WWP
Waste Wise Program
Domestic Registries and Exchanges
Code
Program
CCAR
California Climate Action Registry
CCX
Chicago Climate Exchange
ERT
ERT GHG Registry Program
ECR
Eastern Climate Registry
NHGGR New Hampshire GHG Registry
TCR
The Climate Registry
WVERR Wisconsin Voluntary Emission Reduction Registry
International Registries and Exchanges
Code
Program
EUETS
European Union Greenhouse Gas Emission Trading Scheme (EU ETS)
WBCF
World Bank Carbon Fund
IETS
International Emissions Trading System
WEC
World Energy Council GHG Emissions Reduction Programme
GEIM
La Programa GEI Mexico
CGGCR Canadian GHG Challenge Registry
July 29, 2010
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Expiration Date: TBD
Appendix E. Greenhouse Gases and Global Warming
Potentials (GWP)
GREENHOUSE GAS NAME
GREENHOUSE
GAS CODE
GWP
FORMULA
1
TAR
AR4
2
(1) Carbon Dioxide
CO2
CO2
1
1
(2) Methane
CH4
CH4
23
25
(3) Nitrous Oxide
N2O
N2O
296
298
(4) Hydrofluorocarbons
HFC-23 (trifluoromethane)
15
CHF3
12000
14800
HFC-32 (difluoromethane)
16
CH2F2
550
675
HFC-41 (monofluoromethane)
43
CH3F
97
92
HFC-125 (pentafluoroethane)
17
CHF2CF3
3400
3500
HFC-134 (1,1,2,2-tetrafluoroethane)
44
CHF2CHF2
1100
1100
HFC-134a (1,1,1,2-tetrafluoroethane)
18
CH2FCF3
1300
1430
HFC-143 (1,1,2-trifluorethane)
45
CHF2CH2F
330
353
HFC-143a (1,1,1-trifluoroethane)
46
CF3CH3
4300
4470
HFC-152 (1,2-difluorethane)
47
CH2FCH2F
43
53
HFC-152a (1,1-difluoroethane)
19
CH3CHF2
120
124
HFC-161 (ethyl fluoride)
48
CH3CH2F
12
12
HFC-227ea (heptafluoropropane)
20
CF3CHFCF3
3500
3220
HFC-236cb (1,1,1,2,2,3-hexafluoropropane)
49
CH2FCF2CF3
1300
1340
HFC-236ea (1,1,1,2,3,3-hexafluoropropane)
50
CHF2CHFCF3
1200
1370
HFC-236fa (1,1,1,3,3,3-hexafluoropropane)
41
CF3CH2CF3
9400
9810
HFC-245ca (1,1,2,2,3-pentafluoropropane)
21
CH2FCF2CHF2
640
693
HFC-245fa (1,1,1,3,3-pentafluoropropane)
51
CHF2CH2CF3
950
1030
HFC-365mfc (pentafluorobutane)
52
CF3CH2CF2CH3
890
794
HFC-43-10mee (decafluoropentane)
53
CF3CHFCHFCF2CF3
1500
1640
(5) Perfluorcarbons
PFC-14 (perfluoromethane)
22
CF4
5700
7390
PFC-116 (perfluoroethane)
23
C2F6
11900
12200
PFC-218 (perfluoropropane)
42
C3F8
8600
8830
PFC 3-1-10 (perfluorobutane)
30
C4F10
8600
8860
PFC-318 (perfluorocyclobutane)
54
c-C4F8
10000
10300
PFC-4-1-12 (perfluoropentane)
51
C5F12
8900
9160
PFC 5-1-14 (perfluorohexane)
31
C6F14
9000
9300
(6) Sulfur Hexafluoride
SF6
SF6
22200
22800
3
(7) Chlorofluorocarbons
CFC-11 (trichlorofluoromethane)
01
CCl3F
CFC-12 (dichlorodifluoromethane)
02
CCl2F2
CFC-13 (monochlorotrifluoromethane)
56
CClF3
CFC-113 (Freon 113)
03
CCl2FCClF2
CFC-114 (dichlorotetrafluoroethane)
04
CClF2CClF2
CFC-115 (monochloropentafluoroethane)
05
CF3CClF2
(8) Other Gases
Nitrogen Trifluoride
NF3
NF3
10800
17200
1
Intergovernmental Panel on Climate Change, Climate Change 2001: The Scientific Basis (Cambridge, UK: Cambridge University
Press, 2001). This document was part of the Intergovernmental Panel on Climate Change’s (IPCC’s) Third Assessment Report
(TAR).
2
The IPCC developed revised GWPs for the Fourth Assessment Report (AR4). A complete list of revised GWPs were published in
the errata to Climate Change 2007: The Physical Science Basis, Contribution of Working Group I to the Fourth Assessment Report
of the Intergovernmental Panel on Climate Change [Solomon, S., D. Qin, M. Manning, Z. Chen, M. Marquis, K.B. Averyt, M. Tignor
and H.L. Miller (eds.)]. Cambridge University Press, Cambridge, United Kingdom and New York, NY, USA, 996 pp.,
(http://www.ipcc.ch/pdf/assessment-report/ar4/wg1/ar4-wg1-errata.pdf).
3
The reporting of CFC emissions on Form EIA-1605 is optional. CFC emissions cannot be included in total inventory emissions
since reliable net global warming potentials are not available for these gases. Reductions in CFC emissions may be reported but not
registered.
July 29, 2010
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Voluntary Reporting of Greenhouse Gases
Appendix F. Electricity Emission Factors
Use the electricity factors presented below to estimate emission reductions associated with electricity
generation and consumption as follows:
•
Use 1999-2002 factors to calculate emissions and reductions for Start Year reports for 2002 or
later and Reporting Year reports for 2003 or later.
•
Use 1991-1994 factors to calculate emissions and reductions for Start Year reports for 1990
through 2001 and Reporting Year reports for 1991 through 2002.
•
Use Emission Inventory factors to estimate indirect emissions from the consumption of purchased
electricity.
•
Use Emission Reductions/Avoided Emissions factors as benchmark values for calculating
emission reductions associated with the generation of electricity that displaces power from
higher-emitting sources in Addendum B1, B2, B4, B5, B6, B7, B9, B10, B11, and B14.
•
Use Emission Reductions/Indirect Emissions factors to estimate reductions from the consumption
of purchased electricity.
•
Use domestic factors for electricity generated or consumed in the United States and its territories.
U.S. Average electricity factors are provided for situations where electricity consumption or
generation cannot be disaggregated by region (e.g., Addendum B9).
•
Use foreign electricity factors for electricity consumed or generated in foreign countries.
Regional electricity emission factors are provided for entities reporting emissions and reduction
from foreign sources aggregated by region.
F.1 Domestic Electricity Emission Factors, 1999-2002
a
Emission Inventory
Region
(1) New York, Connecticut, Rhode Island,
Massachusetts, Vermont, New Hampshire and
Maine
(2) New Jersey, Delaware, Pennsylvania,
Maryland, West Virginia, Ohio, Indiana and
Michigan
(3) Illinois and Wisconsin
(4) Missouri, Kentucky, Virginia, Arkansas,
Tennessee, North Carolina, South Carolina,
Louisiana, Mississippi, Alabama and Georgia
(5) Florida
(6) Texas
(7) Oklahoma and Kansas
(8) North Dakota, South Dakota, Nebraska,
Minnesota and Iowa
(9) Colorado, Utah, Nevada, Wyoming and
Montana
(10) New Mexico and Arizona
(11) Oregon, Washington and Idaho
July 29, 2010
Emission Reductions
Avoided
Indirect
b
c
Emissions
Emissions
(Metric tons
(Metric tons
CO2e/MWh)
CO2e/MWh)
Carbon
Dioxide
(Metric tons/
MWh)
Methane
(kg/ MWh)
Nitrous Oxide
(kg/ MWh)
0.466
0.02647
0.00616
0.744
0.793
0.782
0.01404
0.01281
0.900
1.002
0.638
0.01231
0.01048
0.900
1.151
0.690
0.02556
0.01283
0.900
1.005
0.678
0.730
0.867
0.02437
0.01351
0.01315
0.00856
0.00774
0.01236
0.788
0.782
0.900
0.840
0.833
0.990
0.875
0.01392
0.01414
0.900
1.160
0.909
0.01158
0.01377
0.900
1.009
0.658
0.147
0.00762
0.01345
0.00941
0.00337
0.900
0.781
0.970
0.833
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a
Emission Inventory
Emission Reductions
Indirect
Carbon
Avoided
b
c
Emissions
Dioxide
Emissions
(Metric tons/
Methane
(Metric tons
Nitrous Oxide (Metric tons
Region
(kg/ MWh)
(kg/ MWh)
MWh)
CO2e/MWh)
CO2e/MWh)
(12) California
0.350
0.01831
0.00299
0.618
0.659
(13) Hawaii
0.858
0.03443
0.00777
0.849
0.905
(14) Alaska
0.749
0.01163
0.00461
0.859
0.916
(15) U.S. Territories
0.858
0.03443
0.00777
0.849
0.905
U.S. Average
0.676
0.01815
0.01053
0.900
0.959
a
Emission inventory electricity emission factors are based on average emissions intensity of total electric sector generation for
specified state-based regions and include transmission and distribution (T&D) losses incurred in delivering electricity to the point of
use.
b
Avoided emissions benchmark emission factors are based on average emissions intensity of fossil-fired generation for specified
state-based regions, but do not exceed 0.9 metric tons CO2e per MWh. Note that the Avoided emissions benchmarks do not include
(T&D) losses.
c
Indirect emission reductions emission factors for reduced purchases of electricity are based on average emissions intensity of
fossil-fired generation for specified state-based regions and include transmission and distribution (T&D) losses incurred in delivering
electricity to point of use.
Source: U.S. Energy Information Administration, October, 2007.
F.2 Domestic Electricity Emission Factors, 1991-1994
a
Emission Inventory
Carbon
Dioxide
(Metric tons/
MWh)
Emission Reductions
Avoided
Indirect
b
c
Emissions
Emissions
(Metric tons
(Metric tons
CO2e/MWh)
CO2e/MWh)
Methane
Nitrous Oxide
Region
(kg/ MWh)
(kg/ MWh)
(1) New York, Connecticut, Rhode Island,
0.500
0.03281
0.00816
0.817
0.877
Massachusetts, Vermont, New Hampshire and
Maine
(2) New Jersey, Delaware, Pennsylvania,
0.799
0.01442
0.01320
0.900
1.012
Maryland, West Virginia, Ohio, Indiana and
Michigan
(3) Illinois and Wisconsin
0.636
0.01312
0.01083
0.900
1.162
(4) Missouri, Kentucky, Virginia, Arkansas,
Tennessee, North Carolina, South Carolina,
0.681
0.02892
0.01351
0.900
1.025
Louisiana, Mississippi, Alabama and Georgia
(5) Florida
0.718
0.03551
0.01187
0.838
0.899
(6) Texas
0.786
0.01536
0.00891
0.813
0.872
(7) Oklahoma and Kansas
0.857
0.01379
0.01222
0.900
0.988
(8) North Dakota, South Dakota, Nebraska,
0.892
0.01498
0.01461
0.900
1.191
Minnesota and Iowa
(9) Colorado, Utah, Nevada, Wyoming and
0.945
0.01147
0.01497
0.900
1.061
Montana
(10) New Mexico and Arizona
0.690
0.00832
0.01064
0.900
1.024
(11) Oregon, Washington and Idaho
0.124
0.01490
0.00374
0.900
1.057
(12) California
0.345
0.01950
0.00338
0.621
0.666
(13) Hawaii
0.861
0.06238
0.01186
0.856
0.918
(14) Alaska
0.797
0.01440
0.00647
0.900
1.007
(15) U.S. Territories
0.861
0.06238
0.01186
0.856
0.918
U.S. Average
0.687
0.02051
0.01136
0.900
0.987
a
Emission inventory electricity emission factors are based on average emissions intensity of total electric sector generation for
specified state-based regions and include transmission and distribution (T&D) losses incurred in delivering electricity to the point of
use.
b
Avoided emissions benchmark emission factors are based on average emissions intensity of fossil-fired generation for specified
state-based regions, but do not exceed 0.9 metric tons CO2e per MWh. Note that the Avoided emissions benchmarks do not include
(T&D) losses.
c
Indirect emission reductions emission factors for reduced purchases of electricity are based on average emissions intensity of
fossil-fired generation for specified state-based regions and include transmission and distribution (T&D) losses incurred in delivering
electricity to point of use.
Source: U.S. Energy Information Administration, October, 2007
July 29, 2010
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Voluntary Reporting of Greenhouse Gases
F.3 Foreign Electricity Emission Factors, 1999-2002
a
Emission Inventory
Region/Country
OECD North America
Canada
Mexico
d
OECD Europe
Austria
Belgium
Czech Republic
Denmark
Finland
France
Germany
Greece
Hungary
Iceland
Ireland
Italy
e
Luxembourg
Netherlands
Norway
Poland
Portugal
Slovak Republic
Spain
Sweden
Switzerland
Turkey
United Kingdom
OECD Asia
Australia
Japan
Korea
New Zealand
Non-OECD Europe and Eurasia
Albania
Armenia
Azerbaijan
Belarus
Bosnia-Herzegovina
Bulgaria
e
Croatia
Estonia
FYR of Macedonia
Georgia
Gibraltar
Kazakhstan
Kyrgyzstan
e
Latvia
Lithuania
Malta
e
Republic of Moldova
Romania
Russia
Serbia and Montenegro
Slovenia
Tajikistan
July 29, 2010
Carbon
Dioxide
(Metric tons/
MWh)
Methane
(kg/ MWh)
Nitrous Oxide
(kg/ MWh)
0.223
0.593
0.387
0.197
0.289
0.604
0.358
0.239
0.083
0.539
0.887
0.437
0.001
0.699
0.525
0.387
0.479
0.005
0.730
0.511
0.297
0.443
0.048
0.022
0.584
0.475
0.511
0.924
0.417
0.493
0.159
0.513
0.051
0.230
0.613
0.326
0.770
0.492
0.513
0.774
0.773
0.137
0.870
1.293
0.102
0.513
0.165
0.904
0.513
0.426
0.351
0.786
0.369
0.038
0.00390
0.01676
0.00694
0.00377
0.00420
0.00783
0.01181
0.00395
0.00136
0.00637
0.01453
0.01009
0.00003
0.01623
0.01773
0.00694
0.00998
0.00003
0.01084
0.01459
0.00357
0.00923
0.00092
0.00030
0.01135
0.00793
0.00787
0.01008
0.00839
0.00758
0.00307
0.01300
0.00251
0.00950
0.03937
0.02441
0.01074
0.01087
0.01300
0.02085
0.01810
0.00392
0.05168
0.01888
0.00209
0.01300
0.00629
0.05977
0.01300
0.01443
0.01379
0.01291
0.00674
0.00044
0.00351
0.00230
0.00505
0.00207
0.00275
0.01074
0.00831
0.00348
0.00093
0.00779
0.01141
0.00540
0.00001
0.00765
0.00482
0.00505
0.00492
0.00001
0.01528
0.00711
0.00324
0.00631
0.00046
0.00005
0.00628
0.00549
0.00679
0.01290
0.00465
0.00672
0.00084
0.01309
0.00050
0.00095
0.00710
0.00335
0.01544
0.01351
0.01309
0.02810
0.02453
0.00052
0.01034
0.02150
0.00168
0.01309
0.00103
0.01195
0.01309
0.01135
0.00668
0.01828
0.00915
0.00004
Voluntary Reporting of Greenhouse Gases
Emission Reductions
Avoided
Indirect
b
c
Emissions
Emissions
(Metric tons
(Metric tons
CO2e/MWh)
CO2e/MWh)
0.802
0.763
0.694
0.558
0.682
0.782
0.475
0.451
0.849
0.829
0.900
0.673
0.315
0.738
0.649
0.694
0.545
0.410
0.749
0.690
0.706
0.790
0.495
0.379
0.786
0.643
0.808
0.900
0.696
0.842
0.526
0.900
0.685
0.490
0.664
0.328
0.900
0.900
0.900
0.900
0.900
0.853
0.874
0.900
0.407
0.900
0.343
0.900
0.900
0.676
0.403
0.900
0.861
0.475
0.876
0.899
0.749
0.594
0.716
0.854
0.506
0.468
0.912
0.869
1.044
0.773
0.331
0.807
0.693
0.749
0.568
0.442
0.848
0.755
0.750
0.865
0.537
0.408
0.973
0.701
0.963
1.096
0.730
0.892
0.595
1.077
1.025
0.693
0.790
0.369
2.145
1.124
1.077
1.300
1.255
1.007
0.874
1.814
0.605
1.077
0.407
1.051
1.077
0.785
0.463
1.595
0.918
0.554
130
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
a
Emission Inventory
Region/Country
Turkmenistan
Ukraine
Uzbekistan
Non-OECD Asia
Bangladesh
Brunei Darussalam
China (including Hong Kong)
Chinese Taipei
Dem. People's Republic of Korea
India
Indonesia
Malaysia
Myanmar
Nepal
Pakistan
Philippines
Singapore
Sri Lanka
Thailand
Vietnam
f
Other Asia
g
Middle East
Bahrain
Cyprus
Iraq
Islamic Republic of Iran
Israel
Jordan
Kuwait
Lebanon
Oman
Qatar
Saudi Arabia
Syria
United Arab Emirates
Yemen
Africa
Algeria
Angola
e
Benin
e
Botswana
Cameroon
e
Congo
Côte d'Ivoire
Democratic Republic of Congo
Egypt
Eritrea
Ethiopia
Gabon
Ghana
Kenya
Libya
Morocco
e
Mozambique
e
Namibia
Nigeria
July 29, 2010
Carbon
Dioxide
(Metric tons/
MWh)
0.858
0.345
0.497
0.809
0.625
0.830
0.839
0.631
0.630
0.999
0.722
0.528
0.456
0.013
0.482
0.526
0.731
0.384
0.583
0.417
0.469
0.743
0.876
0.851
0.744
0.598
0.839
0.775
0.790
0.754
0.856
0.862
0.816
0.655
0.760
1.029
0.683
0.752
0.386
0.683
0.683
0.016
0.683
0.408
0.004
0.436
0.736
0.011
0.311
0.150
0.393
1.146
0.809
0.683
0.683
0.372
Methane
(kg/ MWh)
0.01951
0.01035
0.01976
0.01607
0.02353
0.02089
0.01458
0.01375
0.00732
0.01664
0.02041
0.01984
0.02336
0.00093
0.03146
0.01554
0.03997
0.02717
0.01967
0.01297
0.02202
0.01917
0.01163
0.03817
0.03809
0.01874
0.01769
0.03787
0.03331
0.04011
0.01821
0.01156
0.02678
0.03129
0.01205
0.05155
0.00977
0.01506
0.01341
0.00977
0.00977
0.00079
0.00977
0.00980
0.00011
0.01365
0.03845
0.00040
0.01011
0.00693
0.01342
0.03699
0.01874
0.00977
0.00977
0.01444
Nitrous Oxide
(kg/ MWh)
0.00195
0.00999
0.00366
0.01447
0.00274
0.00213
0.01841
0.00882
0.00747
0.01959
0.00855
0.00365
0.00318
0.00019
0.00549
0.00777
0.00743
0.00543
0.00489
0.00389
0.00656
0.00507
0.00116
0.00763
0.00762
0.00279
0.01318
0.00746
0.00633
0.00802
0.00258
0.00116
0.00487
0.00564
0.00132
0.01031
0.00955
0.00161
0.00268
0.00955
0.00955
0.00016
0.00955
0.00103
0.00002
0.00177
0.00769
0.00008
0.00177
0.00139
0.00268
0.00705
0.01467
0.00955
0.00955
0.00189
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Emission Reductions
Indirect
Avoided
b
c
Emissions
Emissions
(Metric tons
(Metric tons
CO2e/MWh)
CO2e/MWh)
0.859
1.034
0.796
1.003
0.543
0.599
0.900
1.136
0.664
0.783
0.831
0.893
0.900
1.081
0.845
0.887
0.900
1.645
0.900
1.702
0.865
1.001
0.585
0.623
0.696
1.023
0.823
1.047
0.690
0.945
0.879
1.021
0.734
0.774
0.777
0.941
0.631
0.688
0.900
1.101
0.512
0.609
0.760
0.857
0.877
0.954
0.854
0.909
0.760
0.822
0.626
0.754
0.844
0.875
0.782
0.890
0.792
0.907
0.799
0.943
0.857
1.035
0.863
0.934
0.818
0.873
0.751
1.099
0.761
0.801
0.900
1.482
0.860
0.985
0.756
0.925
0.900
1.275
0.860
0.985
0.860
0.985
0.830
1.076
0.860
0.985
0.635
0.788
0.900
1.188
0.531
0.606
0.742
0.905
0.900
1.060
0.846
1.040
0.875
1.112
0.900
1.447
0.900
1.555
0.868
1.030
0.860
0.985
0.860
0.985
0.621
1.019
131
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
a
Emission Inventory
Emission Reductions
Indirect
Carbon
Avoided
b
c
Emissions
Dioxide
Emissions
(Metric tons/
Methane
(Metric tons
Nitrous Oxide (Metric tons
Region/Country
(kg/ MWh)
(kg/ MWh)
MWh)
CO2e/MWh)
CO2e/MWh)
Senegal
0.892
0.03793
0.00758
0.900
1.545
South Africa
0.911
0.01085
0.01627
0.900
1.069
Sudan
0.540
0.01962
0.00392
0.900
1.221
e
Togo
0.683
0.00977
0.00955
0.860
0.985
Tunisia
0.608
0.01566
0.00196
0.614
0.692
United Republic of Tanzania
0.108
0.00249
0.00105
0.900
1.767
Zambia
0.007
0.00017
0.00006
0.900
1.145
e
Zimbabwe
0.683
0.00977
0.00955
0.860
0.985
h
Other Africa
0.431
0.01631
0.00435
0.794
0.826
Central and South America
0.204
0.00520
0.00170
0.780
0.940
Argentina
0.317
0.00570
0.00101
0.569
0.671
Bolivia
0.401
0.00730
0.00115
0.850
0.968
Brazil
0.093
0.00251
0.00106
0.900
1.140
Chile
0.333
0.00586
0.00417
0.693
0.742
Colombia
0.157
0.00280
0.00185
0.647
0.823
Costa Rica
0.015
0.00057
0.00011
0.900
1.073
Cuba
1.104
0.03956
0.00791
0.900
1.412
Dominican Republic
0.771
0.04458
0.01017
0.850
1.247
Ecuador
0.256
0.01523
0.00304
0.779
1.055
El Salvador
0.302
0.01764
0.00353
0.680
0.774
Guatemala
0.418
0.02068
0.00593
0.822
1.074
Haiti
0.347
0.03417
0.00683
0.720
1.461
Honduras
0.290
0.01656
0.00331
0.765
0.957
Jamaica
0.819
0.03716
0.00743
0.847
0.932
Netherlands Antilles
0.793
0.04090
0.00818
0.796
0.936
Nicaragua
0.650
0.04223
0.00845
0.804
1.202
Panama
0.286
0.01651
0.00330
0.777
0.998
Paraguay
0.000
0.00000
0.00000
0.900
1.970
Peru
0.148
0.00534
0.00135
0.826
0.931
Trinidad and Tobago
0.751
0.00796
0.00080
0.755
0.821
Uruguay
0.055
0.00281
0.00056
0.848
1.043
Venezuela
0.251
0.00628
0.00106
0.854
1.134
i
Other Latin America
0.584
0.03073
0.00614
0.705
0.750
a
Emission inventory electricity emission factors are based on average emissions intensity of total electric sector generation for
specified countries or country-based regions and include transmission and distribution (T&D) losses incurred in delivering electricity
to the point of use.
b
Avoided emissions benchmark emission factors are based on average emissions intensity of fossil-fired generation for specified
countries or country-based regions, but do not exceed 0.9 metric tons CO2e per MWh. Note that the Avoided emissions benchmarks
do not include (T&D) losses.
c
Indirect emission reductions emission factors for reduced purchases of electricity are based on average emissions intensity of
fossil-fired generation for specified countries or country-based regions and include transmission and distribution (T&D) losses
incurred in delivering electricity to point of use.
d
Use the factors for OECD Europe for western European countries not listed (e.g., Andorra, Monaco, Liechtenstein, San Marino,
Vatican City).
e
The weighted average emission factors for the region are provided for countries that import more than 25 percent of electricity
consumed in either or both time periods (1991-1994 or 1999-2002).
f
Use the factors for Other Asia for non-OECD Asian countries not listed.
g
Use the weighted average Middle East factors for the West Bank and Gaza Strip.
h
Use the factors for Other Africa for African countries not listed.
i
Use the factors for Other Latin America for Central and South American countries not listed.
Source: U.S. Energy Information Administration, based on data from the following sources: International Energy Agency (IEA),
Electricity Information Database 2007 and CO2 Emissions from Fuel Combustion Database 2006, http://www.iea.org, October 2007.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
132
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
F.4 Foreign Electricity Emission Factors, 1991-1994
a
Emission Inventory
Region/Country
OECD North America
Canada
Mexico
d
OECD Europe
Austria
Belgium
Czech Republic
Denmark
Finland
France
Germany
Greece
Hungary
Iceland
Ireland
Italy
e
Luxembourg
Netherlands
Norway
Poland
Portugal
Slovak Republic
Spain
Sweden
Switzerland
Turkey
United Kingdom
OECD Asia
Australia
Japan
Korea
New Zealand
f
Non-OECD Europe and Eurasia
f
Albania
f
Armenia
g
Azerbaijan
f
Belarus
f
Bosnia-Herzegovina
f
Bulgaria
e
Croatia
f
Estonia
f
FYR of Macedonia
f
Georgia
f
Gibraltar
f
Kazakhstan
f
Kyrgyzstan
e
Latvia
f
Lithuania
f
Malta
e
Republic of Moldova
f
Romania
f
Russia
f
Serbia and Montenegro
f
Slovenia
f
Tajikistan
July 29, 2010
Carbon
Dioxide
(Metric tons/
MWh)
Methane
(kg/ MWh)
Nitrous Oxide
(kg/ MWh)
0.188
0.558
0.432
0.223
0.366
0.628
0.506
0.249
0.094
0.602
1.020
0.501
0.001
0.788
0.560
0.432
0.588
0.004
0.713
0.569
0.432
0.456
0.056
0.023
0.605
0.644
0.494
0.855
0.430
0.582
0.122
0.521
0.074
0.122
0.723
0.364
0.831
0.534
0.521
0.717
0.873
0.333
0.922
1.355
0.114
0.521
0.218
1.312
0.521
0.468
0.321
0.792
0.363
0.064
0.00357
0.02090
0.00750
0.00434
0.00451
0.00800
0.01102
0.00444
0.00156
0.00708
0.01634
0.01046
0.00005
0.01481
0.02370
0.00750
0.01018
0.00001
0.01104
0.01873
0.00618
0.00728
0.00108
0.00040
0.00878
0.00969
0.01046
0.00992
0.01091
0.01005
0.00226
0.01573
0.00416
0.01512
0.05159
0.02941
0.00703
0.01351
0.01573
0.02234
0.01640
0.00979
0.05229
0.01979
0.00325
0.01573
0.00778
0.04383
0.01573
0.01782
0.01612
0.01346
0.00761
0.00064
0.00317
0.00490
0.00597
0.00203
0.00423
0.01146
0.01309
0.00423
0.00122
0.00858
0.01267
0.00574
0.00001
0.00985
0.00604
0.00597
0.00568
0.00001
0.01587
0.00861
0.00470
0.00682
0.00047
0.00007
0.00656
0.00942
0.00521
0.01284
0.00410
0.00461
0.00049
0.01345
0.00083
0.00236
0.01014
0.00456
0.01032
0.01486
0.01345
0.02870
0.02379
0.00130
0.01046
0.02090
0.00225
0.01345
0.00147
0.01666
0.01345
0.01126
0.00630
0.01895
0.00972
0.00006
Voluntary Reporting of Greenhouse Gases
Emission Reductions
Avoided
Indirect
b
c
Emissions
Emissions
(Metric tons
(Metric tons
CO2e/MWh)
CO2e/MWh)
0.882
0.740
0.769
0.599
0.882
0.786
0.606
0.458
0.900
0.872
0.900
0.778
0.429
0.834
0.710
0.769
0.627
0.654
0.739
0.814
0.791
0.900
0.390
0.541
0.900
0.887
0.777
0.900
0.696
0.900
0.550
0.858
0.512
0.295
0.851
0.356
0.900
0.895
0.858
0.823
0.900
0.452
0.900
0.900
0.395
0.858
0.386
0.900
0.858
0.667
0.355
0.900
0.774
0.517
0.954
0.859
0.829
0.639
0.930
0.855
0.650
0.479
1.006
0.902
1.196
0.879
0.463
0.923
0.764
0.829
0.652
0.703
0.855
0.920
0.857
1.050
0.419
0.583
1.204
0.966
0.821
1.030
0.733
1.106
0.619
0.995
1.025
0.453
1.024
0.396
3.334
1.087
0.995
1.030
1.296
0.544
0.938
1.705
0.469
0.995
0.480
1.451
0.995
0.745
0.394
1.453
0.828
0.581
133
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
a
Emission Inventory
Region/Country
h
Turkmenistan
f
Ukraine
f
Uzbekistan
f
Non-OECD Asia
f
Bangladesh
f
Brunei Darussalam
f
China (including Hong Kong)
f
Chinese Taipei
f
Dem. People's Republic of Korea
f
India
f
Indonesia
f
Malaysia
f
Myanmar
f
Nepal
f
Pakistan
f
Philippines
f
Singapore
f
Sri Lanka
f
Thailand
f
Vietnam
f,i
Other Asia
f,j
Middle East
f
Bahrain
f
Cyprus
f
Iraq
f
Islamic Republic of Iran
f
Israel
f
Jordan
f
Kuwait
f
Lebanon
f
Oman
f
Qatar
f
Saudi Arabia
f
Syria
f
United Arab Emirates
f
Yemen
f,k
Africa
f
Algeria
f
Angola
e
Benin
e
Botswana
f
Cameroon
e
Congo
f
Côte d'Ivoire
f
Democratic Republic of Congo
f
Egypt
f
Eritrea
f
Ethiopia
f
Gabon
f
Ghana
f
Kenya
f
Libya
f
Morocco
e
Mozambique
e
Namibia
f
Nigeria
July 29, 2010
Carbon
Dioxide
(Metric tons/
MWh)
0.521
0.387
0.558
0.778
0.613
1.034
0.839
0.521
0.563
0.963
0.709
0.596
0.477
0.065
0.403
0.516
0.997
0.106
0.658
0.290
0.500
0.756
0.998
0.878
0.648
0.607
0.872
0.916
0.753
0.676
0.899
1.046
0.848
0.589
0.799
0.973
0.724
0.711
0.171
0.724
0.724
0.010
0.724
0.303
0.003
0.519
1.495
0.062
0.269
0.002
0.075
0.882
0.908
0.724
0.724
0.366
Methane
(kg/ MWh)
0.01573
0.01450
0.01730
0.01670
0.02479
0.02037
0.01458
0.01476
0.00450
0.01357
0.02590
0.02517
0.01881
0.00387
0.02399
0.02985
0.03971
0.00516
0.02559
0.01131
0.02652
0.02439
0.01121
0.03805
0.03665
0.01938
0.02120
0.03601
0.02551
0.03437
0.01779
0.01134
0.02770
0.03017
0.01286
0.04627
0.01304
0.01491
0.00359
0.01304
0.01304
0.00044
0.01304
0.01830
0.00011
0.01702
0.03707
0.00269
0.00614
0.00009
0.00175
0.04359
0.02611
0.01304
0.01304
0.01505
Nitrous Oxide
(kg/ MWh)
0.01140
0.01196
0.00365
0.01391
0.00283
0.00208
0.01841
0.00776
0.00658
0.01672
0.00832
0.00532
0.00245
0.00077
0.00408
0.00687
0.00739
0.00103
0.00714
0.00350
0.00700
0.00512
0.00112
0.00761
0.00733
0.00316
0.01233
0.00706
0.00453
0.00687
0.00256
0.00113
0.00507
0.00558
0.00143
0.00925
0.01040
0.00163
0.00072
0.01040
0.01040
0.00009
0.01040
0.00366
0.00002
0.00277
0.00741
0.00054
0.00096
0.00002
0.00035
0.00872
0.00860
0.01040
0.01040
0.00213
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Emission Reductions
Indirect
Avoided
b
c
Emissions
Emissions
(Metric tons
(Metric tons
CO2e/MWh)
CO2e/MWh)
0.858
0.995
0.863
0.965
0.679
0.752
0.900
1.113
0.668
0.863
0.900
1.087
0.900
1.081
0.828
0.878
0.900
1.613
0.900
1.552
0.898
1.022
0.706
0.778
0.900
1.479
0.900
1.242
0.702
0.916
0.856
1.019
0.900
1.043
0.900
1.366
0.707
0.782
0.900
1.531
0.550
0.575
0.792
0.876
0.900
1.048
0.881
0.934
0.667
0.697
0.690
0.790
0.877
0.918
0.900
1.018
0.755
0.818
0.814
0.936
0.900
1.036
0.900
1.111
0.850
0.916
0.732
1.034
0.800
0.886
0.900
1.258
0.900
1.020
0.720
0.865
0.900
3.068
0.900
1.020
0.900
1.020
0.887
1.046
0.900
1.020
0.632
0.759
0.900
1.138
0.665
0.744
0.900
1.754
0.823
0.928
0.900
1.127
0.835
0.906
0.900
1.870
0.885
1.219
0.900
1.043
0.900
1.020
0.900
1.020
0.595
0.912
134
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
a
Emission Inventory
Emission Reductions
Indirect
Carbon
Avoided
b
c
Emissions
Dioxide
Emissions
(Metric tons/
Methane
(Metric tons
Nitrous Oxide (Metric tons
Region/Country
(kg/ MWh)
(kg/ MWh)
MWh)
CO2e/MWh)
CO2e/MWh)
f
Senegal
0.935
0.03362
0.00668
0.900
1.170
f
South Africa
0.931
0.01102
0.01650
0.900
1.077
f
Sudan
0.394
0.01526
0.00305
0.900
1.449
e
Togo
0.724
0.01304
0.01040
0.900
1.020
f
Tunisia
0.701
0.02176
0.00356
0.709
0.791
f
United Republic of Tanzania
0.172
0.00435
0.00118
0.900
1.830
f
Zambia
0.011
0.00015
0.00009
0.900
1.581
e
Zimbabwe
0.724
0.01304
0.01040
0.900
1.020
f
Other Africa
0.442
0.01644
0.00389
0.847
0.887
f,l
Central and South America
0.189
0.00517
0.00145
0.900
1.080
f
Argentina
0.358
0.00816
0.00178
0.753
0.939
f
Bolivia
0.398
0.00567
0.00082
0.900
1.062
f
Brazil
0.057
0.00136
0.00065
0.900
1.408
f
Chile
0.212
0.00357
0.00305
0.900
1.295
f
Colombia
0.228
0.00368
0.00291
0.866
1.102
f
Costa Rica
0.138
0.00538
0.00108
0.900
1.052
f
Cuba
1.097
0.03931
0.00786
0.900
1.465
f
Dominican Republic
0.808
0.03977
0.00963
0.900
1.324
f
Ecuador
0.216
0.01083
0.00217
0.900
1.198
f
El Salvador
0.322
0.01369
0.00274
0.900
1.157
f
Guatemala
0.291
0.01379
0.00276
0.845
0.968
f
Haiti
0.233
0.01332
0.00266
0.900
1.775
f
Honduras
0.081
0.00657
0.00131
0.604
0.848
f
Jamaica
0.978
0.03587
0.00717
0.900
1.114
f
Netherlands Antilles
0.791
0.04030
0.00806
0.794
0.920
f
Nicaragua
0.450
0.02419
0.00484
0.891
1.222
f
Panama
0.325
0.01293
0.00259
0.900
1.450
f
Paraguay
0.000
0.00001
0.00000
0.900
1.397
f
Peru
0.184
0.00871
0.00173
0.881
1.091
f
Trinidad and Tobago
0.770
0.00817
0.00082
0.776
0.871
f
Uruguay
0.058
0.00293
0.00059
0.876
1.103
f
Venezuela
0.234
0.00455
0.00069
0.786
0.970
f
Other Latin America
0.686
0.02953
0.00590
0.855
0.904
a
Emission inventory electricity emission factors are based on average emissions intensity of total electric sector generation for
specified countries or country-based regions and include transmission and distribution (T&D) losses incurred in delivering electricity
to the point of use.
b
Avoided emissions benchmark emission factors are based on average emissions intensity of fossil-fired generation for specified
countries or country-based regions, but do not exceed 0.9 metric tons CO2e per MWh. Note that the Avoided emissions benchmarks
do not include (T&D) losses.
c
Indirect emission reductions emission factors for reduced purchases of electricity are based on average emissions intensity of
fossil-fired generation for specified countries or country-based regions and include transmission and distribution (T&D) losses
incurred in delivering electricity to point of use.
d
Use the factors for OECD Europe for western European countries not listed (e.g., Andorra, Monaco, Liechtenstein, San Marino,
Vatican City).
e
The weighted average emission factors for the region are provided for countries that import more than 25 percent of electricity
consumed in either or both time periods (1991-1994 or 1999-2002).
f
The weighted average emission factors for 1992-1994 are provided because data for 1991 were unavailable.
g
The weighted average emission factors for 1993-1994 are provided because 1991 and 1992 data were unavailable for Azerbaijan.
h
The weighted average emission factors for the region are provided since 1991-1994 data were not available for Turkmenistan.
i
Use the factors for Other Asia for non-OECD Asian countries not listed.
j
Use the weighted average Middle East factors for the West Bank and Gaza Strip.
k
Use the factors for Other Africa for African countries not listed.
l
Use the factors for Other Latin America for Central and South American countries not listed.
Source: U.S. Energy Information Administration, based on data from the following sources: International Energy Agency (IEA),
Electricity Information Database 2007 and CO2 Emissions from Fuel Combustion Database 2006, http://www.iea.org, October 2007.
July 29, 2010
Voluntary Reporting of Greenhouse Gases
135
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Appendix G. Estimation Methods and Ratings
Source
Carbon Dioxide From CoalFired Plants
Carbon Dioxide From Natural
Gas Combustion
July 29, 2010
Method
Stationary Combustion
CEM or mass balance supervised by a
regulatory agency with an emission factor
derived from plant-specific, periodic
analyses
Mass balance, measured consumption,
emission factor derived from plant-specific,
periodic analyses
Mass balance, measured consumption,
emission factor derived from plant-specific,
single analysis
Estimated consumption based on
purchases or deliveries, emission factor
derived from plant-specific, periodic
analyses
Mass balance, measured consumption
based on actual heating value and default
emission factor based on coal rank
Mass balance, measured consumption, and
default emission factor based on coal rank
Estimated consumption based on
purchases or deliveries, emission factor
derived from plant-specific, single analysis
Estimated consumption based on
purchases or deliveries and actual heating
value, and default emission factor based on
coal rank
Estimated consumption based on
purchases or deliveries, and default
emission factor based on coal rank
Continuous emissions monitoring or mass
balance supervised by a regulatory agency
Mass balance where heating value is
known and falls between 975 and 1100 Btu
per standard cubic foot.
Mass balance where heating value and gas
composition are known and used to
calculate a situation-specific emission factor
(even if outside 975-1100 Btu/scf range)
Mass balance based on purchases where
only volume is known (no heating value);
Mass balance of “rich” flare gas, or low Btu
gas, where composition is not known
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
C01A1
A
C01A2
B
C01B1
B
C01B2
B
C01B3
C
C01C1
C
C01C2
C
C01C3
D
C01D1
A
C02A1
A
C02A2
A
C02A3
B
C02B1
C
C02C1
136
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide From Fuel Oil
Liquid Petroleum Gas
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Continuous emissions monitoring (CEM) or
mass balance supervised by a regulatory
agency
Mass balance based on actual fuel
consumption and specific information about
fuel quality (e.g., heating value, density, or
actual carbon content)
Mass balance based on actual fuel
consumption (or purchases if stock
changes are not material), with default
emission factors
Mass balance based on fuel purchases
(with no correction for stock change, if
material) and specific information about fuel
quality (e.g., heating value, density, or
actual carbon content)
Mass balance based on fuel purchases
(with no correction for stock change, if
material) and default emission factors
Continuous emission monitoring (CEM)
Rating
Code
A
C03A1
A
C03A2
B
C03B1
B
C03B2
C
C03C1
A
Mass balance using actual quantities
consumed (volume, weight, or heating
value), the actual product is known and is
propane or butane.
Mass balance using actual quantities
consumed (volume, weight, or heating
value), the actual LPG product is not known
or is ethane or isobutane.
Mass balance using fuel purchase data
(with no correction for stock change, if
material)
July 29, 2010
Voluntary Reporting of Greenhouse Gases
C04A1
A
C04A2
B
C04B1
C
C04C1
137
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Methane & Nitrous Oxide
Emissions From Stationary
Source Combustion
Carbon Dioxide Emissions
From Refinery Fuel Gas
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Continuous Emission Monitor
Fuel consumption measurements and unitspecific emission factors based on periodic,
site-specific measurements
Fuel consumption measurements and
default emission factors that are publicly
documented and have been widely
reviewed and adopted by a public agency,
a standards-setting organization or an
industry group.
Fuel consumption estimates and unitspecific emission factors based on periodic,
site-specific measurements*
Fuel consumption measurement and
default emission factors based on other
published sources.
Fuel consumption estimates and default
emission factors that are publicly
documented and have been widely
reviewed and adopted by a public agency,
a standards-setting organization or an
industry group*
Fuel consumption estimates and default
emission factors based on other published
sources.
Continuous emission monitoring (or mass
balance), supervised by a regulatory
agency
Mass balance, based on measured volume
and density and composition from multiple
gas samples
Mass balance, based on measured volume
and density, and composition from a single
gas sample
Mass balance, based on measured heat
content, and a default emission factor that
is publicly documented and has been
widely reviewed and adopted by a public
agency, a standards-setting organization or
an industry group
Mass balance, based on measured heat
content, using other default emission factor
Mass balance, based on volume, using
assumed heating value and default
emissions factor
Voluntary Reporting of Greenhouse Gases
Rating
A
Code
C05A1
A
C05A2
B
C05B1
B
C05B2
C
C05C1
C
C05C2
D
C05D1
A
C06A1
A
C06A2
B
C06B1
B
C06B2
C
C06C1
D
C06D1
138
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide Emissions
from Petroleum Coke
Carbon Dioxide From Venting
and Flaring of Natural Gas
Carbon Dioxide From
Combustion of Crude Oil
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Continuous emission monitoring or mass
balance supervised by a regulatory agency
Mass balance based on measured
consumption or complete estimate of
usage (including catalyst coke and nonfuel use, if applicable), actual carbon
content composition of coke based on
periodic samples
Mass balance based on measured
consumption or complete estimate of
usage (including catalyst coke and nonfuel use, if applicable), actual carbon
content based on one-time sample
Mass balance based on measured
consumption or complete estimate of
usage, plus a default emission factor that
is publicly documented and has been
widely reviewed and adopted by a public
agency, a standards-setting organization
or an industry group
Mass balance based on measured
consumption or complete estimate of
usage, plus other default emission factor
Mass balance based on marketable coke
only (if catalyst coke is being combusted)
and default emission factor
Measured venting or flaring; actual
composition data from periodic samples
Measured venting or flaring; actual
composition data from single sample
Measured venting or flaring; assumed
composition using a published default
emission factor that is publicly documented
and has been widely reviewed and
adopted by a public agency, a standardssetting organization or an industry group
Estimated venting or flaring; assumed
composition using default emission factors
Measured fuel use; emission factor based
on actual composition data from periodic
samples
Measured fuel use; assumed composition
using a published default emission factor
that is publicly documented and has been
widely reviewed and adopted by a public
agency, a standards-setting organization
or an industry group
Estimated fuel use; emission factor based
on actual composition data from single
sample
Estimated fuel use; assumed composition
using default emission factor
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
C07A1
A
C07A2
B
C07B1
B
C07B2
C
C07C1
D
C07D1
A
C08A1
B
C08B1
B
C08B2
C
C08C1
A
C09A1
B
C09B1
C
C09C1
D
C09D1
139
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide Emissions
From Selected PetroleumBased Waste Fuels
Carbon Dioxide From Waste
Fuels
Carbon Dioxide From NonFuel Use of Fossil Fuel
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Continuous emission monitoring or mass
balance supervised by a regulatory
agency.
Measured fuel use; emission factor based
on actual composition data
Measured fuel use; assumed composition
using default emission factor that is
publicly documented and has been widely
reviewed and adopted by a public agency,
a standards-setting organization or an
industry group
Estimated fuel use; emission factor based
on actual composition data
Estimated fuel use; assumed composition
using default emission factor
Continuous emissions monitoring or mass
balance supervised by a regulatory
agency; prorated by measured waste
composition
Continuous emissions monitoring or mass
balance supervised by a regulatory
agency, prorated by default waste
composition.
Measured quantity of waste combusted
multiplied by a default emission factor that
is publicly documented and has been
widely reviewed and adopted by a public
agency, a standards-setting organization
or an industry group
Measured quantity of waste combusted
times other default emission factor
Facility-level mass balance computation
with known product composition
Facility-level mass balance computation
with default emissions factor for product
Product consumption multiplied by default
emission factor multiplied by a default
fraction combustion for asphalt, lubricants,
and solvents
Product consumption multiplied by default
emission factor multiplied by default
fraction sequestered (petrochemical
feedstocks).
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
C10A1
A
C10A2
B
C10B1
C
C10C1
D
C10D1
A
C11A1
B
C11B1
B
C11B2
C
C11C1
A
C12A1
B
C12B1
B
C
C12B2
C12C1
140
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide From
Unspecified Fuels
Carbon Dioxide Emissions
From Highway Vehicles
July 29, 2010
Voluntary Reporting of Greenhouse Gases
Method
CEM or mass balance supervised by a
regulatory agency with an emission factor
derived from plant-specific, periodic analyses
Mass balance, measured consumption,
emission factor derived from plant-specific,
periodic analyses
Mass balance, measured consumption,
emission factor derived from plant-specific,
single analysis
Mass balance, estimated consumption based
on purchases or deliveries, and emission
factor derived from plant-specific, periodic
analyses
Mass balance, measured consumption, and
default emission factor that is publicly
documented and has been widely reviewed
and adopted by a public agency, a
standards-setting organization or an industry
group
Mass balance, measured consumption, and
other default emission factor
Mass balance, estimated consumption based
on purchases or deliveries, and emission
factor derived from plant-specific, single
analyses
Mass balance, estimated consumption based
on purchases or deliveries, and default
emission factor that is publicly documented
and has been widely reviewed and adopted
by a public agency, a standards-setting
organization or an industry group
Estimated consumption based on purchases
or deliveries, and other default emission
factor
Mobile Sources
Mass balance based on fuel volume burned,
or bulk purchase data adjusted for stock
change used with measured density or
heating value and carbon content or with
default emission factors
Mass balance based on bulk fuel purchase
not accounting for stock change used with
default emission factors
Mass balance based on distance traveled
and fuel economy data, or hours,
horsepower-hours, or ton-distance shipped
and fuel consumption per unit activity data
used with default emissions factors
Mass balance based on fuel price or
expenditure data used with default emissions
factors
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Rating
Code
A
C13A1
A
C13A2
B
C13B1
B
C13B2
B
C13B3
C
C13C1
C
C13C2
C
C13C3
D
C13D1
A
D01A1
B
D01B1
C
D01C1
D
D01D1
141
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide Emissions
From Off-Road Vehicles,
Including Diesel Locomotives
Carbon Dioxide Emissions
From Water Borne Vessels
Carbon Dioxide Emissions
From Aircraft
July 29, 2010
Voluntary Reporting of Greenhouse Gases
Method
Mass balance based on actual fuel
consumed or via bulk purchase data that
accounts for stock change used with
measured density or hearing values and
carbon content or with default emissions
factors
Mass balance using fuel consumption based
on bulk purchase not accounting for stock
change used with default emissions factors
Mass balance based on distance traveled
and fuel economy for each engine, or hours,
horsepower hours of operation, or tondistance shipped and fuel consumed per unit
activity data used with default emissions
factors
Mass balance based on fuel price data only
or default factors for fuel consumption per
unit activity data used with default emissions
factors
Mass balance based on actual fuel quantities
consumed or bulk purchase records
accounting for stock change used with
measured density, heating value, and/or
carbon content and/or with specific fuel type
and default emissions factors
Mass balance based on bulk fuel purchase
data not adjusted for stock change used with
default emissions factors
Mass balance based on distance traveled
data and fuel economy for each engine, or
hours, horsepower hours of operation, or
ton-distance shipped and specific information
on fuel consumed per unit activity data used
with default emissions factors
Mass balance based on fuel price data only
or default factors for fuel consumption per
unit of activity data used with default
emissions factors
Mass balance based on measured quantities
loaded into vehicle or bulk purchase records
accounting for stock change used with
measured density or heating value, and
carbon content or with default emissions
factors
Mass balance fuel consumption volume from
bulk purchase data not adjusted for stock
change used with default emissions factors
Mass balance based on distance traveled
and fuel economy for each engine, or hours,
horsepower hours, or ton-distance shipped
and specific information on fuel consumed
per unit activity data used with default
emissions factors
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Rating
Code
A
D02A1
B
D02B1
C
D02C1
D
D02D1
A
D03A1
B
D03B1
C
D03C1
D
D03D1
A
D04A1
B
D04B1
C
D04C1
142
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide Emissions
From Aircraft (continued)
Methane and Nitrous Oxide
From Highway Vehicles
Methane and Nitrous Oxide
From Off-Road and Water
Borne Vessels
Methane and Nitrous Oxide
From Aircraft
Hydrofluorocarbons From
Mobile Refrigeration and AirConditioning
July 29, 2010
Voluntary Reporting of Greenhouse Gases
Method
Mass balance based on fuel price data only
or default factors for fuel consumption per
unit of activity data used with default
emissions factors
Inference based on vehicle distance traveled
or fuel consumption and an emission factor
for specific vehicle types, provided
combustion and emission control technology
are known for each vehicle
Inference based on total vehicle distance
traveled for an uncharacterized vehicle mix
and weighted average emissions factor
Inference based on fuel or energy
consumption data and specific IPCC
emissions factors
Inference based other activity data (e.g.,
distance traveled) to calculate fuel
consumption, with model specific fuel
economy factors and IPCC emissions factors
Inference based on default/generic fuel
economy values and available activity data
with IPCC emissions factors
Inference based on individual jet engine
aircraft LTO and cruise data and IPCC
default emissions factors
Known fuel/energy consumption and either
LTO approach or emissions per kilogram fuel
with IPCC default emissions factors
Inference based on other activity data (e.g.,
distance traveled) use to calculate fuel
consumption used with IPCC emission
factors, provided fuel economy data are
model-specific
Inference using other activity data (e.g.,
hours) and default/generic fuel economy
values with IPCC default emissions factors
Mass balance, provided specific features and
data availability
Mass balance based on emission factors
(percent) for initial charge, annual leakage,
capacity remaining at disposal, and recovery
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Rating
Code
D
D04D1
A
D05A1
B
D05B1
A
D06A1
B
D06B1
C
D06C1
A
D07A1
B
D07B1
C
D07C1
D
D07D1
A
D08A1
C
D08C1
143
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Nitrous Oxide Emissions
From Adipic Acid Production
Carbon Dioxide Emissions
From Aluminum Production
PFCs From Aluminum
Production
Sulfur Hexafluoride From
Aluminum Production
Carbon Dioxide From
Ammonia Production
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Industrial Processes
Direct measurement, either continuous
emissions monitoring or periodic direct
measurements
Default emission factors using known
destruction and utilization factors for an
abatement technology, with default
emissions factors
Default emission factors, using utilization
factors, and reflecting an uncontrolled
stream or default factor for an abatement
technology
Mass balance based on quantity and
composition of reducing agents
consumed
Mass balance based on default anode
composition values and data on quantity
of reducing agent consumed
Default emission factors
Smelter-specific slope factors based on
representative field measurements
Technology-specific slope factors (or
over-voltage coefficients), anode effect
frequency and duration (or anode effect
over-voltage), and production data
Inference method based on most recent
IPCC default emissions factors
Inference method using purchase data
Continuous emission monitoring or
periodic direct measurement
Mass balance when carbon content of
feedstock fuel is known
Mass balance using default carbon
content value
Default emissions factor of 1.26 tons
carbon dioxide per ton ammonia
produced
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
E01A1
B
E01B1
C
E01C1
A
E02A1
B
E02B1
B
E02B2
A
E03A1
B
E03B1
C
E03C1
A
E04A1
A
E05A1
B
E05B1
B
E05B2
C
E05C1
144
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide From Cement
Production – Clinker
Production
Carbon Dioxide From
Discarded Bypass/Cement
Kiln Dust
Carbon Dioxide From
Hydrogen Production
Carbon Dioxide Emissions
From Iron and Steel
Production – Reducing
Agents
Carbon Dioxide Emissions
From Iron and Steel
Production – Furnace
Additives
Carbon Dioxide Emissions
from Iron and Steel
Production – Crude Iron
Production
Carbon Dioxide Emissions
From Iron and Steel
Production – Conversion of
Iron to Steel (Including
Secondary Steel Production
in Electric Arc Furnaces)
Carbon Dioxide Emissions
From Iron and Steel
Production –Electrode
Consumption in Electric Arc
Furnaces
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Mass balance, clinker method, based on
measured calcium oxide content of clinker
Clinker method based on measured
magnesium oxide content of clinker
Mass balance, cement method, based on
plant-specific raw material data and
clinker content of cement
Default emission factor (includes
emissions from CaO and MgO)
Default clinker and additive fraction
values for appropriate cement production
mix
Default emissions factor of 0.499 tons
carbon dioxide per ton cement produced
Direct measurement
Plant-specific clinker emission factors and
data on portion of CKD that is calcined
Inference based on discarded CKD value,
assumed equal to two percent of CO2
from clinker production
Direct measurement
Mass balance based on feedstock use of
fossil fuels
Plant-specific data on reducing agent
consumption and its carbon content
Default reducing agent emissions factors
Plant-specific data on furnace additive
consumption and emission factor
Mass balance using default furnaceadditive emission factor
Plant-specific data on crude inputs and
production and carbon contents
Default carbon content of inputs and
crude product
Mass balance based on plant-specific
carbon content of pig iron and steel
Mass balance based on default carbon
content values
Mass balance using graphite electrode
consumption and plant-specific emissions
factors
Mass balance using graphite electrode
consumption and default emission factor
Estimation using steel production and
default emission factor
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
E06A1
A
E06A2
A
E06A3
B
E06B1
B
E06B2
C
E06C1
A
E07A1
B
E07B1
C
E07C1
A
E08A1
A
E08A2
A
E09A1
B
E09B1
A
E10A1
A
E10A2
A
E11A1
B
E11B1
A
E12A1
B
E12B1
A
E13A1
B
E13B1
B
E13B2
145
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide Emissions
From Iron and Steel
Production – All Processes
Carbon Dioxide Emissions
From Lime Production
Carbon Dioxide From
Limestone and Dolomite Use
Carbon Dioxide From
Methanol Production
Methane From Methanol
Production
Methane From Petrochemical
Production
Nitrous Oxide From Nitric
Acid Production
Carbon Dioxide From Soda
Ash Production
Carbon Dioxide From Soda
Ash Use
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Direct measurement
Production times default emissions factor
for integrated iron and steel production
Production times specific or default
emissions factor for secondary steel
production in EAF
Mass balance using limestone production
emissions factor based on measured lime
purity value
Mass balance using IPCC default
emissions factor
Mass balance using plant-specific
emissions factor based on limestone and
dolomite content of the raw material
consumed
Mass balance using IPCC default
emissions factor
Continuous emissions monitoring or other
direct measurement
Mass balance accounting for carbon
content of feedstock fuel minus carbon
content of methanol
Direct measurement
Use of IPCC provided default factors
Continuous emissions monitoring or other
Direct measurement
Use of IPCC provided default factors
Continuous emissions monitoring
Emission factors based on direct, periodic
measurement of plant emissions
Default emissions factors for uncontrolled
and non-selective catalytic reduction
control technologies that are publicly
documented and have been widely
reviewed and adopted by a public agency,
a standards-setting organization or an
industry group
Other default emissions factors for
uncontrolled and non-selective catalytic
reduction control technologies
Emissions factor based on production of
soda ash from trona
Emissions factor based on molecular
weight ratio of carbon dioxide to soda ash
Voluntary Reporting of Greenhouse Gases
Rating
A
Code
E14A1
C
E14C1
C
E14C2
A
E15A1
B
E15B1
A
E16A1
B
E16B1
A
E17A1
B
E17B1
A
B
E18A1
E18B1
A
E19A1
B
A
E19B1
E20A1
A
E20A2
B
E20B1
C
E20C1
A
E21A1
A
E22A1
146
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Methane From Coal Mining
(all sources)
Carbon Dioxide and
Methane From Oil and
Natural Gas Industries
Methane From Wastewater
and Sludge Handling
Nitrous Oxide From
Disposed Wastewater
Treatment Effluent
Methane From Landfilling
HFCs From HCFC-22
Production
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Direct measurement
Direct measurement augmented by indirect
estimates based on default emissions
factors
Indirect estimates based on default
emissions factors
Direct, site-specific measurements of
emissions or all mass balance factors
Mass-balance approach, using measured
activity data and emission factors that are
publicly documented and widely reviewed
and adopted by a public agency, a
standards-setting organization or an industry
group
Mass –balance approach, using measured
activity data and other emission factors
Emission factors derived from measured
wastewater stream composition data
Default emissions factors based on general
activity data
Direct measurement
IPCC method using measured, site-specific
effluent data
IPCC method using default values
IPCC First-Order Decay model using sitespecific waste and landfill parameters
Publicly available models, including
LandGem and EMCON, that rely on userdefined data elements
Publicly-available models, including
LandGem and EMCON, that rely on default
parameters
Mass balance using single (or limited
number of) year(s), site-specific DOC data
Mass balance, default DOC values
Continuous emissions monitoring
Emission estimates based on
representative, periodic direct measurement
Default, uncontrolled emission factor,
abatement/capture technology reduction
value if applicable, that are publicly
documented and have been widely reviewed
and adopted by a public agency, a
standards-setting organization or an industry
group
Other default, uncontrolled emissions factor,
abatement/capture technology reduction
value if applicable
Voluntary Reporting of Greenhouse Gases
Rating
A
Code
E23A1
B
E23B1
C
E23C1
A
E24A1
B
E24B1
C
E24C1
A
E25A1
B
E25B1
A
E26A1
B
E26B1
C
E26C1
A
E27A1
A
E27A2
B
E27B1
C
E27C1
D
A
E27D1
E28A1
A
E28A2
B
E28B1
C
E28C1
147
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Sulfur Hexafluoride From
Electrical Equipment
Industrial Use and
Production of High-GWP
Gases
SF6 Emissions From
Magnesium Production
Methods for High GWP
Gases From Semiconductor
Manufacturing
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Mass balance by life cycle stage of
Equipment (IPCC Tier 3a)
Mass Balance at the manufacturer and
facility level (IPCC Tier 3b)
Inference method by life cycle stage using
emissions factors (IPCC Tier 2a)
Inference method using IPCC default
emissions factors (IPCC Tier 2b)
Potential emissions method (IPCC Tier 1)
EPA Climate Leaders Material Balance
Method
EPA Climate Leaders Simplified Material
Balance Method
IPCC Good Practice Guidance Mass
Balance, or Top-Down Approach that
does not rely on emissions factors
IPCC Revised 1996 Guidelines Tier 2Actual Emissions, using facility-specific
emissions factors that have been
demonstrated to be highly representative
California Climate Change Action Registry
General Reporting Protocol Mass Balance
Method
IPCC Revised 1996 Guidelines Tier 2Actual Emissions, using reasonably
representative facility-specific emissions
factors
IPCC Revised 1996 Guidelines Tier 2Actual Emissions, using country-specific
emissions factors
IPCC Revised 1996 Guidelines Tier 1Potential Emissions
Mass balance using consumption data
Default emissions factors based on
general activity data
Mass Balance at the specific process or
tool level (IPCC Tier 2a)
Mass Balance at the process-or tool- type
level (IPCC Tier 2b)
Mass Balance using WRI/WBCSD
spreadsheets with plant-specific data
Mass Balance using site-specific
purchase and abatement data (IPCC Tier
2c)
Mass Balance using WRI/WBCSD
spreadsheets with default factors
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
E29A1
A
E29A2
B
E29B1
C
E29C1
D
E29D1
A
E30A1
A
E30A2
A
E30A3
A
E30A4
A
E30A5
B
E30B1
C
E30C1
D
E30D1
A
E31A1
B
E31B1
A
E32A1
B
E32B1
B
E32B2
C
E32C1
C
E32C2
148
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Other Industrial Process
Emissions
Carbon Dioxide, Methane,
and Nitrous Oxide From
Electricity Imports
Carbon Dioxide, Methane,
and Nitrous Oxide From
Steam or Hot Water Imports
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Continuous direct measurement (CEM) of
actual emissions source; or emissions
factor based upon multiple, recent,
regularly repeated, on-site, direct
measurements of sources, multiplied by
measured activity data. Activity data
measure the actual relevant activity,
rather than an indirect indicator of that
activity (for instance, fuel consumption
rather than purchases).
Emissions factor based on limited direct
measurements of source or
representative sample multiplied by
measured activity data. Activity data
measure actual use, rather than
purchases (if applicable).
Default emissions factor multiplied by
measured activity data; or emissions
factor based on single measurement
multiplied by estimated activity data.
Default emissions factor multiplied by
estimated activity data or static one-time
monitoring.
Indirect Emissions
Measured electricity consumption in
conjunction with source-specific,
generator-type or default regional or
default national emission rates and
system-specific or default transmission
loss factor
“Area” method estimate of electricity
consumption in conjunction with sourcespecific, generator-type or default regional
or default national emission rates and
system-specific or default transmission
loss factor
Measured heat consumption in
conjunction with source-specific emission
factor and source-specific or default
transmission loss factor
Measured heat consumption in
conjunction with default emission factor
and source-specific or default
transmission loss factor
“Area” method estimate of heat
consumption in conjunction with sourcespecific emission factor and sourcespecific or default transmission loss factor
“Area” method estimate of heat
consumption in conjunction with default
emission factor and source-specific or
default transmission loss factor
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
E33A1
B
E33B1
C
E33C1
D
E33D1
A
F01A1
B
F01B1
A
F02A1
B
F02B1
C
F02C1
D
F02D1
149
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide, Methane,
and Nitrous Oxide From
Chilled Water Purchases
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Measured chilled water consumption data
used in conjunction with source-specific
COP, a source-specific or default
transmission loss factor, and A-rated
emissions calculation method
Measured chilled water consumption data
used in conjunction with source-specific
COP, source-specific or default
transmission loss factor, and B-rated
emissions calculation method
Measured chilled water consumption data
used in conjunction with source-specific
COP, source-specific or default
transmission loss factor, and C-rated
emissions calculation method
Measured chilled water consumption data
used in conjunction with source-specific
COP, source-specific or default
transmission loss factor, and D-rated
emissions calculation method
Measured chilled water consumption data
used in conjunction with default COP, a
source-specific or default transmission
loss factor, and A-rated emissions
calculation method
Measured chilled water consumption data
used in conjunction with default COP,
source-specific or default transmission
loss factor, and B-rated emissions
calculation method
Measured chilled water consumption data
used in conjunction with default COP,
source-specific or default transmission
loss factor, and C- or D-rated emissions
calculation method
“Area” method estimates of chilled water
consumption used in conjunction with
source-specific COP, a source-specific or
default transmission loss factor, and Arated emissions calculation method
“Area” method estimates of chilled water
consumption used in conjunction with
source-specific COP, source-specific or
default transmission loss factor, and B-,
C-, or D-rated emissions calculation
method
“Area” method estimates of chilled water
consumption in conjunction with default
COP and source-specific or default
transmission loss factor
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
F03A1
B
F03B1
C
F03C1
D
F03D1
B
F03B2
C
F03C2
D
F03D2
C
F03C3
D
F03D3
D
F03D4
150
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Carbon Dioxide, Methane,
and Nitrous Oxide From
Electricity and Heat
Purchases From Offsite CHP
Plants
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Measured steam/electricity consumption
data used in conjunction with sourcespecific emission rates, a source-specific
or default transmission loss factor, and an
A-rated method to determine CHP plant
emissions
Measured steam/electricity consumption
data used in conjunction with sourcespecific emission rates, a source-specific
or default transmission loss factor, and a
B-rated method to determine CHP plant
emissions
Measured steam/electricity consumption
data used in conjunction with sourcespecific emission rates, a source-specific
or default transmission loss factor, and a
C-rated method to determine CHP plant
emissions
Measured steam/electricity consumption
data used in conjunction with sourcespecific emission rates, a source-specific
or default transmission loss factor, and a
D-rated method to determine CHP plant
emissions
Measured steam/electricity consumption
data used in conjunction with the method
provided for allocating fuel use to thermal
and electrical generation, a specific or
default transmission loss factor, and an Arated method to determine CHP plant
emissions
Measured steam/electricity consumption
data used in conjunction with the method
provided for allocating fuel use to thermal
and electrical generation, a specific or
default transmission loss factor, and a Brated method to determine CHP plant
emissions
Measured steam/electricity consumption
data used in conjunction with the method
provided for allocating fuel use to thermal
and electrical generation, a specific or
default transmission loss factor, and a Cor D-rated method to determine CHP
plant emissions
“Area” method estimate of
steam/electricity consumption used in
conjunction with source-specific emission
rates, a source-specific or default
transmission loss factor, and an A-rated
method to determine CHP plant emissions
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
F04A1
B
F04B1
C
F04C1
D
F04D1
B
F04B2
C
F04C2
D
F04D2
C
F04C3
151
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Source
Carbon Dioxide, Methane,
and Nitrous Oxide From
Electricity and Heat
Purchases From Offsite CHP
Plants (continued)
Method
“Area” method estimate of
steam/electricity consumption used in
conjunction with source-specific emission
rates, a source-specific or default
transmission loss factor, and a B-, C-, or
D-rated method to determine CHP plant
emissions
“Area” method estimate of
steam/electricity consumption used in
conjunction with the method provided for
allocating fuel use to thermal and
electrical generation, and a specific or
default transmission loss factor
Geologic Sequestration of Carbon Dioxide
Fugitive Emissions From the
Direct measurement and at least annual
Extraction of Naturally
content analysis of gas
Occurring CO2
Mass balance based on before-and-after
measurements, minus amount extracted
(Equation 1)
Fugitive Emissions During the Difference between upstream and
Extraction of CO2 From
downstream measurements based on
Anthropogenic Source
CEM or flow meter data (Equation 2)
Difference between upstream and
downstream measurements based on
annual emissions data (Equation 2)
Manufacturer’s specifications for capture
technology employed (Equation 3)
Fugitive Emissions During
Direct actual measurements at pipeline
Transport and Processing
beginning and endpoint (Equation 4)
Direct actual measurements at tank fill
and delivery (Equation 5)
Annual measurements at pipeline
beginning and endpoint (Equation 4)
Estimating without direct measurement
(Equation 6)
Use of EPA VOC emissions factors
(Equation 7)
Fugitive Emissions of CO2
Monitoring system for direct CO2 loss
During Injection and
measurement
Extraction for Enhanced
Difference in CO2 needed and CO2 stored
Resource Recovery
(Equation 8)
Post-Injection Seepage of
Monitoring plan using 4D seismic,
Carbon Dioxide to the
reservoir pressure monitoring, formation
Atmosphere
fluid monitoring, shallow water sampling
(if present) and soil gas surveys
Monitoring plan using one or more
measurement techniques in both
categories
Federal or state approved monitoring plan
Monitoring plan using measurement
techniques in only one category
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Rating
Code
D
F04D3
D
F04D4
A
G01A1
B
G01B1
A
G02A1
B
G02B1
C
G02C1
A
G03A1
A
G03A2
B
G03B1
C
G03C1
D
G03D1
A
G04A1
D
G04D1
A
G05A1
B
G05B1
B
G05B2
C
G05C1
152
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Source
Method
Agricultural Emissions and Sequestration
Methane and Nitrous Oxide
Inference using improved emission
From Enteric Fermentation
factors
Inference using default emission factors
Methane and Nitrous Oxide
Inference using emission factors
From Livestock Waste
specific to livestock category and
waste management system -Methane
(CH4)
Methane and Nitrous Oxide
Inference using default emission factors
From Crop Residue Burning
Methane From Rice
Inference using default emission factors
Cultivation
Nitrous Oxide From
Agricultural Soils (Including
Inference using specific activity data and
Nitrogen Application and
default N2O emission factor
Organic Soils)
Carbon Dioxide Emissions on Direct measurement of organic soil
Cultivated Organic Soils
carbon stock change with associated
uncertainty levels less than or equal to 15
percent
Direct measurement of organic soil
carbon stock change with associated
uncertainty levels greater than 15 percent
Inference using default emission actors
Carbon Dioxide From Lime
Applications to Agricultural
Inference using default emission factors
Soils
Carbon Dioxide Fluxes on
Model-based estimates of CO2 flux on
Mineral Soils
mineral soils with uncertainty estimates
less than or equal to 15 percent
Model-based estimates of CO2 Flux on
mineral soils with uncertainty estimates
greater than 15 percent
Direct measurement of mineral soil
carbon stocks with uncertainty estimates
less than or equal to 15 percent
Direct measurement of mineral soil
carbon stocks with uncertainty estimates
greater than 15 percent
Inference using default emission and
sequestration factors
Forestry
Forest Ecosystem Carbon
Estimates from look-up tables that match
Pools
specific site conditions and management
practices, as documented using
independent data or information.
Use of the USFS COLE model or an
approved model, validated with data
specific to the site conditions and
management practices.
Sampling with quantified accuracy
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Rating
Code
A
H01A1
B
H01B1
B
H02B1
B
H03B1
B
H04B1
B
H05B1
A
H06A1
B
H06B1
B
H06B2
B
H07B1
A
H08A1
B
H08B1
A
H08A2
B
H08B2
C
H08C1
A
I01A1
A
I01A2
A
I01A3
153
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Source
Forest Ecosystem Carbon
Pools (continued)
Harvested Wood Products
Carbon Stocks
July 29, 2010
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Method
Estimates in look-up tables adapted to
specific site conditions and management
practices.
Use of an approved model that is
parameterized specifically for site
conditions and management practices.
Use of the U.S. Forest Service COLE
model
Typical application of regional look-up
tables that generally match the site
conditions and management practices
Use of an approved model that generally
matches site conditions and
management practices.
Use of look-up tables for site conditions
and management practices that are not
represented accurately by the tables.
Use of an approved model validated with
data specific to the product mix of the
entity
Use of specific data on harvest or
product mix and default decay factors
provided in Appendix C of the Part I
appendix
Use of aggregate data on harvest and
default decay factors provided in
Appendix C of the Part I appendix
Voluntary Reporting of Greenhouse Gases
Rating
Code
B
I01B1
B
I01B2
B
I01B3
C
I01C1
C
I01C2
D
I01D1
A
I02A1
B
I02B1
C
I02C1
154
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Appendix H. Fuel Emission Factors
H.1 Carbon Dioxide Emission Factors for Stationary Combustion1
Fuel
Emission Factor
Units
Anthracite
103.62
kg CO2 / MMBtu
Bituminous
93.46
kg CO2 / MMBtu
Sub-bituminous
97.09
kg CO2 / MMBtu
Lignite
96.43
kg CO2 / MMBtu
Electric Power Sector
95.26
kg CO2 / MMBtu
Industrial Coking
93.98
kg CO2 / MMBtu
Other Industrial
94.38
kg CO2 / MMBtu
Residential/Commercial
95.48
kg CO2 / MMBtu
54.01
kg CO2 / MMBtu
5.401
kg CO2 / therm
Coal2
Natural Gas
2
Pipeline Natural Gas
HHV of 975 - 1000 Btu/scf
HHV of 1000 - 1025 Btu/scf
52.91
kg CO2 / MMBtu
5.291
kg CO2 / therm
HHV of 1025 - 1050 Btu/scf
53.06
kg CO2 / MMBtu
5.306
kg CO2 / therm
HHV of 1050 - 1075 Btu/scf1
53.46
kg CO2 / MMBtu
5.346
kg CO2 / therm
HHV of 1075 - 1100 Btu/scf
53.72
kg CO2 / MMBtu
5.372
kg CO2 / therm
Weighted National Average (1029
53.06
kg CO2 / MMBtu
Btu/scf)
5.306
kg CO2 / therm
Flared Natural Gas
54.71
kg CO2 / MMBtu
5.471
kg CO2 / therm
73.15
kg CO2 / MMBtu
2
Petroleum Fuels
Middle Distillate Fuels (No. 1, No. 2, No. 4 fuel
oil, diesel, home heating oil)
Jet Fuel ( Jet A, JP-8)
70.88
kg CO2 / MMBtu
Kerosene
72.31
kg CO2 / MMBtu
Heavy Fuel Oil (No. 5, 6 fuel oil), bunker fuel1
78.80
kg CO2 / MMBtu
Ethane
59.58
kg CO2 / MMBtu
Propane
63.10
kg CO2 / MMBtu
Isobutane
65.08
kg CO2 / MMBtu
N-butane
64.97
kg CO2 / MMBtu
Unspecified LPG
62.33
kg CO2 / MMBtu
Refinery (Still) Gas
64.20
kg CO2 / MMBtu
Crude Oil
74.43
kg CO2 / MMBtu
Petroleum Coke
102.12
kg CO2 / MMBtu
July 29, 2010
Voluntary Reporting of Greenhouse Gases
155
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Fuel
Emission Factor
Units
85.97
9.98
66.53
71.28
411.37
41.14
2,539.80
kg CO2 / MMBtu
kg CO2 / gallon
kg CO2 / MMBtu
kg CO2 / MMBtu
kg CO2 / short ton MSW
kg CO2 / MMBtu MSW
kg CO2 / short ton plastics
Other Fuels
Tires/Tire Derived Fuel3
Waste Oil4,5
Waste Oil Blended with Residual Fuel Oil4
4
Waste Oil Blended with Distillate Fuel Oil
6,7
Municipal Solid Waste (MSW)
Municipal Solid Waste (MSW)6,7
Plastics Portion of MSW6
1
All factors assume 100 percent combustion except those for MSW, which assume 98 percent combustion.
Energy Information Administration, Documentation for Emissions of Greenhouse Gases in the United States 2005, DOE/EIA-0638
(2005), October 2007, Tables 6-1, 6-2, 6-4, and 6-5.
3
U.S. Department of Energy, Technical Guidelines Voluntary Reporting of Greenhouse Gases (1605(b)) Program, Chapter 1, Part
C, Stationary Source Combustion, January 2007.
4
U.S. EPA, AP 42, Fifth Edition, Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources,
http://www.epa.gov/ttn/chief/ap42/ch01/final/c01s11.pdf.
5
To convert to an energy basis (kg/MMBtu), divide by the heating value of the oil in units of MMBtu/gal, if known. If the heating value
is not known, use the default values below depending on whether the waste oil is blended with residual or distillate fuel oil.
6
Emissions factors for components of MSW calculated from 2006 data in U.S. Environmental Protection Agency, Inventory of U.S.
Greenhouse Gas Emissions and Sinks: 1990-2006, Public Review Draft, February 22, 2008, Section 3.9 and Annex 3.6. Weighted
emission factor based on MSW composition for 2006 reported in U.S. Environmental Protection Agency, 2006 MSW
Characterization Data Tables, http://www.epa.gov/epaoswer/non-hw/muncpl/pubs/06data.pdf.
7
Emissions from other components of municipal solid waste are excluded because they are considered to be biogenic.
2
H.2 Carbon Dioxide Emission Factors for Transportation Fuels1
Emission Factors
Transportation Fuel
Aviation Gasoline
Biodiesel
-B100
-B20
-B10
-B5
-B2
Diesel Fuel (No. 1 and No. 2)
Ethanol/Ethanol Blends
-E100
-E85
-E10 (Gasohol)
Methanol/Methanol Blends
-M85
Motor Gasoline
Jet Fuel, Kerosene
Natural Gas
Propane
Residual Fuel (No. 5 and No. 6
Fuel Oil)
Pounds CO2 Per Unit of Volume
Kilograms CO2 Per Million Btu
18.33 per gallon
69.19
0 per gallon
17.89 per gallon
20.13 per gallon
21.25 per gallon
21.92 per gallon
22.37 per gallon
0.00
59.44
66.35
69.76
71.80
73.15
0 per gallon
2.93 per gallon
17.59 per gallon
0.00
14.71
65.94
10.68 per gallon
19.54 per gallon
21.09 per gallon
120.36 per 1000 cubic feet
12.67 per gallon
64.01
70.88
70.88
53.06
63.10
26.00 per gallon
78.80
1
Emissions factors calculated from data in: (1) Energy Information Administration, Documentation for Emissions of Greenhouse
Gases in the U.S. 2005, DOE/EIA-0638 (2005), October 2007, Tables 6-1, 6-4, and 6-5. (Non-biogenic carbon content and gross
heat of combustion for motor gasoline and diesel (distillate fuel)). (2) U.S. Department of Energy, Office of Energy Efficiency and
Renewable Energy, Alternative Fuels & Advanced Vehicles Data Center, Fuel Properties web page
(http://www.eere.energy.gov/afdc/fuels/properties.html). (Biodiesel gross heat of combustion). (3) Energy Information Administration,
Annual Energy Review 2006, DOE/EIA-0384(2006), June 2007, Table A3, p. 361. (Gross heat of combustion for ethanol). (4) Stacy
C. Davis and Susan W. Diegel, Transportation Energy Data Book, Edition 26, Oak Ridge National Laboratory, ORNL-6978, 2007,
Table B.7 Tables 6.7 and B.4. (Density and gross heat of combustion of methanol.)
July 29, 2010
Voluntary Reporting of Greenhouse Gases
156
U.S. Department of Energy
U.S. Energy Information Administration
Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
H.3 Generic Methane and Nitrous Oxide Emission Factors for Stationary Fuel Combustion
Methane
(g /MMBtu)
Source
Nitrous Oxide
(g/MMBtu)
Coal
Residential
Commercial
Industry
Electricity Generation
Petroleum
Residential
Commercial
Industry
Electricity Generation
Natural Gas
Residential
Commercial
Industry
Electricity Generation
Wood
Residential
Commercial
Industry
Electricity Generation
301
10
10
1
1.5
1.5
1.5
1.5
10
10
3
3
0.6
0.6
0.6
0.6
5
5
1
1
0.1
0.1
0.1
0.1
253
253
25
25
3.2
3.2
3.2
3.2
Source: Intergovernmental Panel on Climate Change (IPCC), 2006 IPCC Guidelines for National Greenhouse Gas Inventories, pp.
2.16 - 2.23, Tables 2.2, 2.3, 2.4 and 2.5 (Revised April 2007).
Note: Energy units are in higher heating value (HHV). Lower heating value (LHV) assumed to be 5 percent lower than HHV for coal
and petroleum, 10 percent lower for natural gas, and 20 percent lower for wood.
H.4 Specific Methane and Nitrous Oxide Emission Factors for Biogenic Fuel Sources
Source
Wood residue (industrial)
1
Conventional wood stove (non-catalytic)1
Advanced wood stove (non-catalytic)1
Advanced wood stove (catalytic)1
Residential fireplace1
Charcoal manufacture1
Municipal solid waste (MSW)2
Methane
Nitrous Oxide
0.0953 kg / MMBtu residue
0.0059 kg / MMBtu
15 kg / metric ton wood
8 kg / metric ton wood
5.8 kg / metric ton wood
NA
55 kg / metric ton charcoal
NA
NA
NA
NA
0.15 kg / metric ton
NA
0.044 kg / metric ton
Notes: Conventional wood stoves includes all stoves without any emission reduction technology or design features, in most cases
manufactured before July 1, 1986. Advanced noncatalytic wood stoves are those units that employ non-catalytic emission reducing
technology or features. Typical noncatalytic design includes baffles and secondary combustion chambers. Advanced catalytic
stoves are equipped with a ceramic or metal honeycomb device, called a combustor or converter, that is coated with a noble metal
such as platinum or palladium. The catalyst material reduces the ignition temperature of the unburned volatile organic compounds
(VOC) and carbon monoxide (CO) in the exhaust gases, thus promoting the ignition and combustion of these gases.
1
Sources: Environmental Protection Agency, Compilation of Air Pollutant Emission Factors (AP-42), Fifth Edition, Volume I:
Stationary Point and Area Sources.
2
U.S. Environmental Protection Agency, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2006, EPA 430-R-08-005,
April 15, 2008, Section 3.9.
NA=not available.
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H.5 Methane and Nitrous Oxide Emissions Factors for Highway Vehicles
Vehicle Type/ Control
Technology
Gasoline Passenger Cars
EPA Tier 2
Low Emission Vehicles
EPA Tier 1
EPA Tier 0
Oxidation Catalyst
Non-Catalyst
Uncontrolled
Gasoline Light-Duty Trucks
EPA Tier 2
Low Emission Vehicles
EPA Tier 1
EPA Tier 0
Oxidation Catalyst
Non-Catalyst
Uncontrolled
Gasoline Heavy-Duty Vehicles
EPA Tier 2
Low Emission Vehicles
EPA Tier 1
EPA Tier 0
Oxidation Catalyst
Non-Catalyst Control
Uncontrolled
Diesel Passenger Cars
Advanced
Moderate
Uncontrolled
Diesel Light-Duty Trucks
Advanced
Moderate
Uncontrolled
Diesel Heavy-Duty Vehicles
Advanced
Moderate
Uncontrolled
Motorcycles
Non-Catalyst Control
Uncontrolled
NO
CH
NO
CH
(g/mi)
(g/mi)
(g/km)
(g/km)
2004 and Later
2000-2003
1995-1999
1981-1994
1975-1980
1973-1974
1972 and Earlier
0.0036
0.0150
0.0429
0.0647
0.0504
0.0197
0.0197
0.0173
0.0105
0.0271
0.0704
0.1355
0.1696
0.1780
0.0022
0.0093
0.0267
0.0402
0.0313
0.0122
0.0122
0.0108
0.0065
0.0168
0.0437
0.0842
0.1054
0.1106
2005 and Later
2001-2004
1995-2000
1986-1994
1975-1985
1973-1974
1972 and Earlier
0.0066
0.0157
0.0871
0.1056
0.0639
0.0218
0.0220
0.0163
0.0148
0.0452
0.0776
0.1516
0.1908
0.2024
0.0041
0.0098
0.0541
0.0656
0.0397
0.0135
0.0137
0.0101
0.0092
0.0281
0.0482
0.0942
0.1186
0.1258
2004 and Later
1998-2003
1996-2003
1996 and Later
1996 and Later
1985-1995
1984 and Earlier
0.0134
0.0320
0.1750
0.2135
0.1317
0.0473
0.0497
0.0333
0.0303
0.0655
0.2630
0.2356
0.4181
0.4604
0.0083
0.0199
0.1087
0.1327
0.0818
0.0294
0.0309
0.0207
0.0188
0.0407
0.1634
0.1464
0.2598
0.2861
1996 and Later
1983-1995
1982 and Earlier
0.0010
0.0010
0.0012
0.0005
0.0005
0.0006
0.0006
0.0006
0.0008
0.0003
0.0003
0.0004
1996 and Later
1983-1995
1982 and Earlier
0.0015
0.0014
0.0017
0.0010
0.0009
0.0011
0.0009
0.0009
0.0011
0.0006
0.0006
0.0007
1996 and Later
1983-1995
1982 and Earlier
0.048
0.048
0.048
0.0051
0.0051
0.0051
0.030
0.030
0.030
0.0032
0.0032
0.0032
1996 and Later
1995 and Earlier
0.0069
0.0087
0.0672
0.0899
0.0043
0.0054
0.0418
0.0559
2
Model Year
4
2
4
Source: U.S. Environmental Protection Agency. Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2005, EPA 430-R07-002, Annex 3.2, (April 2007), web site: http://www.epa.gov/climatechange/emissions/usinventoryreport.html.
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H.6 Methane and Nitrous Oxide Emission Factors for Alternative Fuel Vehicles
Vehicle Type/Control Technology
Light Duty Vehicles
Methanol
CNG
LPG
Ethanol
Heavy Duty Vehicles
Methanol
CNG
LNG
LPG
Ethanol
Buses
Methanol
CNG
Ethanol
N2O (g/mi)
CH4 (g/mi)
N2O (g/km)
CH4 (g/km)
0.067
0.050
0.067
0.067
0.018
0.737
0.037
0.055
0.0416
0.0311
0.0416
0.0416
0.0112
0.4580
0.0230
0.0342
0.175
0.175
0.175
0.175
0.175
0.066
1.966
1.966
0.066
0.197
0.1087
0.1087
0.1087
0.1087
0.1087
0.0410
1.2216
1.2216
0.0410
0.1224
0.175
0.175
0.175
0.066
1.966
0.197
0.1087
0.1087
0.1087
0.0410
1.2216
0.1224
Source: U.S. Environmental Protection Agency. Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2005, EPA 430-R07-002, Annex 3.2, (April 2007), web site: http://www.epa.gov/climatechange/emissions/usinventoryreport.html.
H.7 Methane and Nitrous Oxide Emission Factors for Non-Highway Mobile Combustion
Vehicle Type/Fuel Type
Ships and Boats
Residual
Distillate
Gasoline
Locomotives
Diesel
Agricultural Equipment
Gas
Diesel
Construction
Gas
Diesel
Other Non-Highway
All “Other” Categories1
Aircraft
Jet Fuel
Aviation Gasoline
N2O
(g/kg fuel)
CH4
(g/kg fuel)
N2O
(g/gal fuel)
CH4
(g/gal fuel)
0.08
0.08
0.08
0.23
0.23
0.23
0.30
0.26
0.22
0.86
0.74
0.65
0.08
0.25
0.26
0.80
0.08
0.08
0.45
0.45
0.22
0.26
1.26
1.44
0.08
0.08
0.18
0.18
0.22
0.26
0.51
0.58
0.08
0.18
0.22
0.51
0.10
0.04
0.09
2.64
0.31
0.11
0.27
7.05
1
“Other" includes snowmobiles and other recreational equipment, logging equipment, lawn and garden equipment, railroad
equipment, airport equipment, commercial equipment, and industrial equipment. (Assumes gasoline fuel.)
Source: U.S. Environmental Protection Agency. Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2005, EPA 430-R07-002, Annex 3.2, (April 2007), web site: http://www.epa.gov/climatechange/emissions/usinventoryreport.html.
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Appendix I. System and Fuel Codes for Purchased
Steam and Chilled/Hot Water
System Codes
Code
System Type
Steam/Hot Water Systems
WB
FB
AC
CC
EC
OT
UK
Water-tube Boiler
Fire-tube Boiler
Chilled Water Systems
Absorption Chiller
Engine-Driven Chiller
Electric-Driven Chiller
Other or Unknown Systems
Other
Unknown
Fuel Codes
Code
DF
KS
LG
MG
PC
RF
WO
ME
LF
FG
NG
PR
AC
BC
SB
LC
BM
GE
SL
TF
WW
MS
BD
EL
OT
UK
July 29, 2010
Fuel Type
Petroleum Products
Distillate Fuel (Nos. 1, 2, and 4 Fuel Oil and Diesel)
Kerosene
Liquified Petroleum Gases
Motor Gasoline
Petroleum Coke
Residual Fuel (Nos. 5 and 6 Fuel Oil)
Waste Oil
Natural Gas and Other Gaseous Fuels
Methane
Landfill Gas
Flare Gas
Natural Gas (Pipeline)
Propane
Coal
Anthracite
Bituminous
Subbituminous
Lignite
Renewable Fuels
Biomass
Geothermal
Solar
Tires/Tire-Derived Fuel
Wood and Wood Waste
Municipal Solid Waste
Biodiesel
Electricity
Electricity
Other or Unknown Fuels
Other
Unknown
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Appendix J. Emission Source Codes
Emission Source Category
Stationary Combustion
Mobile Sources
Sector-Specific Industrial
Processes: General
Sector-Specific Industrial
Processes: Energy
Sector-Specific Industrial
Processes: Waste Handling
Sector-Specific Industrial
Processes: High GWP Gases
Other Industrial Process
Sources
Agricultural Sources
July 29, 2010
Code
Emission Source
DIRECT EMISSIONS
SC01
Fossil fuel combustion
SC02
Non-standard fuel combustion
SC03
Waste fuels combustion
SC04
Biomass combustion
SC05
Nonfuel use of fossil fuels
MS01
Highway vehicles
MS02
Off-road vehicles
MS03
Marine vessels
MS04
Aircraft
MS05
Mobile refrigeration and air-conditioning
IP01
Adipic acid production
IP02
Aluminum production
IP03
Ammonia production
IP04
Cement production
IP05
Hydrogen production
IP06
Iron and steel production
IP07
Lime production
IP08
Limestone and dolomite use
IP09
Methanol production
IP10
Nitric acid production
IP11
Soda ash production and use
EI01
Coal mines
EI02
Oil and natural gas industries
WI01
Domestic and industrial wastewater handling
WI02
Landfills
GI01
Aluminum production
GI02
HCFC-22 production
GI03
Industrial production and use of high GWP gases
GI04
Magnesium production
GI05
Semiconductor manufacture
IP99
Other industrial processes
AS01
AS02
AS03
AS04
AS05
AS06
AS07
AS08
AS09
AS10
Enteric fermentation
Livestock waste
Residue burning
Rice cultivation – 1st harvest
Rice cultivation – 2nd (“ratoon”) harvest
Agricultural soils – nitrogen application
Agricultural soils – organic soils
Lime application
Cultivation of organic soils
Other
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Emission Source Category
Fugitive Emissions
Associated With Geologic
Reservoirs
Indirect Emissions From
Purchased Energy
Other Indirect Emissions
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Code
GR01
GR02
GR03
Emission Source
CO2 extracted from natural geologic reservoir
CO2 extracted from man-made geologic reservoir
Fugitive emissions from the extraction of naturally
occurring CO2
GR04
Fugitive emissions from the extraction of CO2 from
anthropogenic sources
GR05
Fugitive emissions during transport and processing
GR06
Fugitive emissions during injection and extraction for
enhanced resource recovery
GR07
Post-injection seepage from permanent geologic storage
reservoir
INDIRECT EMISSIONS
PE01
Electricity
PE02
Steam
PE03
Hot water
PE04
Chilled water
OI01
Employee commuting
OI02
Manufacture and sale of energy efficient products
OI03
Consumption of energy-intensive products
OI04
Other
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Appendix K. GDP Price Deflators
Chained Weighted Price Deflator for GDP[2000=100]
Year
1987
Value
73.058
1988
75.567
1989
78.421
1990
81.448
1991
84.334
1992
86.335
1993
88.242
1994
90.101
1995
91.978
1996
93.729
1997
95.384
1998
96.462
1999
97.880
2000
100.000
2001
102.260
2002
103.916
2003
106.151
2004
109.163
2005
112.807
2006
116.481
2007
119.817
2008
122.376
Source: Bureau of Economic Analysis, Table 1.1.9. Implicit Price Deflators for Gross
Domestic Product, http://www.bea.gov/national/nipaweb/SelectTable.asp?Selected=Y.
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Appendix L. Possible Output Measures
NAICS
Code
51
62
111
113
212
221
311
313
314
321
322
323
324
July 29, 2010
NAICS Description With Possible Output Metrics
Information
number of employees
square feet of building space
Health Care and Social Assistance
number of beds
square feet of building space
Crop Production
metric tons of product/raw material
Forestry and Logging
Acres
Mining (except Oil and Gas)
metric tons of product/raw material
Utilities
kilowatt-hours
revenue (U.S. $)
Food Manufacturing
short tons of product/raw material
metric tons of product/raw material
lbs of product/raw material
kg of product/raw material
sacks (flour)
bushels (wheat)
kilolitres of product/raw material
Textile Mills
1000 lbs of product/raw material
million hours (spindle)
bales (cotton)
lbs (tie cord)
square yards (fabrics)
Textile Product Mills
dozens
square yards of product/raw material
Wood Product Manufacturing
billion board feet
cubic meters of product/raw material
Paper Manufacturing
short tons of product/raw material
metric tons of product/raw material
Printing and Related Support Activities
square meter
Petroleum and Coal Products Manufacturing
million barrels per day (crude throughput)
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NAICS
Code
325
326
327
331
332
333
334
335
336
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NAICS Description With Possible Output Metrics
Chemical Manufacturing
short tons of product/raw material
metric tons of product/raw material
gallons of product/raw material
cubic ft. of product/raw material
Plastics and Rubber Products Manufacturing
metric tons of product/raw material
Nonmetallic Mineral Product Manufacturing
billion square feet of product/raw material
short tons of product/raw material
metric tons of product/raw material
metric tons (clinker)
kilograms of product/raw material
million dozen tumblers
million dozen cookware
million dozen stemware
million pieces tableware
1000 bricks
square meters (wall tile)
Primary Metal Manufacturing
million tons by metal smelted
1000 short tons steel in process
1000 short tons of finished steel
1000 metric tons of product by grade-carbon & furnace type
1000 metric tons of product by grade-alloy & furnace type
1000 metric tons of product by grade-stainless & furnace type
Fabricated Metal Product Manufacturing
million tons by metal
1000 units by type
Machinery Manufacturing
units by type
units by fuel-gas
units by fuel-diesel
units by fuel-Natural Gas
units by fuel-LPG
Computer and Electronic Product Manufacturing
units by type
square meters of silicon
Electrical Equipment, Appliance, and Component Manufacturing
units by type
1000 lbs gross (by type of material)
1000 units (if product type does not change substantially over time)
Transportation Equipment Manufacturing
units by type-cars
units by type-trucks
number of vehicles
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NAICS
Code
337
339
442
486
523
531
541
562
611
812
813
814
921
928
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NAICS Description With Possible Output Metrics
Furniture and Related Product Manufacturing
units by type
Miscellaneous Manufacturing
units by type
Furniture and Home Furnishings Stores
units by type
Pipeline Transportation
barrels of throughput
Securities, Commodity Contracts, and Other Financial Investments
and Related Activities
square feet of building space
Real Estate
square feet of building space by category of commercial building
number of apartments
number of residential units
Professional, Scientific, and Technical Services
square feet of building space
number of employees
Waste Management and Remediation Services
tons of waste processed
Educational Services
number of students
number of faculty
Personal and Laundry Services
lbs laundry cleaned
number of employees
Religious, Civic, Professional, and Similar Organizations
by category of commercial building
square feet of building space
Private Households
Household
number of inhabitants
Executive, Legislative, and Other General Government Support
number of employees
square feet of building space
by category of commercial building
National Security and International Affairs
square feet of building space
number of employees
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Appendix M. Action Type Codes
Action Category
1. Electricity Generation,
Transmission, and
Distribution
2. Cogeneration and Waste
Heat Recovery
3. Energy End Use
4. Transportation and OffRoad Vehicles
Code
A01
A02
A03
A04
A05
A06
A07
A08
A09
A10
A11
A12
A13
A14
A15
B01
C01
C02
C03
C04
C05
C06
C07
C08
C09
C10
C11
D01
D02
D03
D04
D05
D06
D07
D08
D09
D10
D11
D12
D13
D14
D15
D16
D17
D18
July 29, 2010
Action Type
General Generation, transmission & distribution projects
General generator improvements
Heat rate or other efficiency improvement
Availability improvement
Fuel Switching
Increase in low-emitting capacity
Decrease in high-emitting capacity
Dispatching changes only
Zero/low emitting power purchases
General transmission and distribution
High-efficiency transformers
Reconductoring
Distribution voltage upgrade
Other transmission & distribution improvements
Other electricity generation, transmission, and distribution
projects/activities
Cogeneration and waste heat recovery
General energy use
Equipment and appliances improvement or replacement
Lighting and lighting control
Load control
Heating, ventilation, and air-conditioning
Building shell improvement
Motor and motor drive
Fuel switching
Industrial power systems
Urban forestry (energy effects only)
Other energy end-use projects/activities
General transportation
Marketing/manufacturing of more efficient vehicles
Marketing/manufacturing of more efficient vehicle
components
Marketing/manufacturing of alternative fuel vehicles
Operation of more efficient vehicles
Use of more efficient vehicle components
Operation of alternative fuel vehicles
General trip reduction (demand modification)
Demand Modification: Carpooling/Vanpooling
Demand Modification: Mass transit
Demand Modification: Employee parking buyout
Demand Modification: Telecommuting
Demand Modification: Other
Service efficiency improvements
Driver/operator training
Infrastructure improvement
Accelerated scrappage
Other transportation and off-road vehicle projects/activities
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Action Category
5. Waste Treatment and
Disposal —Methane
Voluntary Reporting of Greenhouse Gases
Code
E01
E02
E03
E04
E05
E06
E07
E08
E09
E10
E11
E12
E13
6. Agriculture —Methane and
Nitrous Oxide
F01
F02
F03
F04
F05
F06
F07
F08
F09
7. Oil and Natural Gas
Systems and Coal Mining —
Methane
G01
G02
G03
G04
G05
G06
G07
G08
G09
G10
G11
G12
G13
July 29, 2010
Form Approved
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Expiration Date: TBD
Action Type
General Waste Treatment and Disposal: Methane emissions
avoidance or recovery
Landfills: General methane emissions avoidance or recovery
Landfills: Landfill gas recovery for energy use
Landfills: Flaring landfill gas
Landfills: Modification of waste stream (e.g., yard waste bans)
Landfills: Other
Wastewater Treatment: General methane emissions
avoidance or recovery
Wastewater Treatment: Biogas recovery for energy use
Wastewater Treatment: Flaring biogas
Wastewater Treatment: Modification of waste stream (e.g.
elimination of pulp and paper wastes)
Wastewater Treatment: Altered waste treatment (may be
mechanical or chemical)
Wastewater Treatment: Other
Other waste treatment and disposal activities reducing
emissions of methane
General Agriculture: Methane and nitrous oxide emissions
avoidance or recovery
General Livestock: General methane emissions avoidance or
recovery
Livestock: Reduced livestock production
Livestock: Improved livestock productivity
Livestock: Recovery of biogas from manure for energy use
Livestock: Recovery and flaring of biogas from manure
Cropland: Rice field drainage
Cropland: Improved nutrients management
Other agricultural projects reducing emissions of methane or
nitrous oxide
General oil and natural gas systems and coal mining
Oil and Natural Gas Systems: General methane emissions
avoidance or recovery
Oil and Natural Gas Systems: Reduction in gas vented due to
increased flaring
Oil and Natural Gas Systems: Reduction in gas vented due to
recovery for energy
Oil and Natural Gas Systems: Changes in operation and
maintenance practices
Oil and Natural Gas Systems: Equipment replacement and
upgrade
Oil and Natural Gas Systems: Natural gas reinjection
Oil and Natural Gas Systems: Reduced production
Oil and Natural Gas Systems: Recovery of glycol dehydrator
emissions
Oil and Natural Gas Systems: Other methane emissions
avoidance or recovery
Coal Mining: General methane emissions avoidance or
recovery
Coal Mining: Decreased production
Coal Mining: Change in operation and maintenance
procedures
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Action Category
7. Oil and Natural Gas
Systems and Coal Mining —
Methane (continued)
8. Carbon Sequestration
9. Halogenated Substances
10. Other Emission Reduction
Projects
July 29, 2010
Voluntary Reporting of Greenhouse Gases
Code
G14
G15
G16
G17
G18
G19
G20
G21
H01
H02
H03
H04
H05
H06
H07
H08
H09
H10
H11
I01
I02
I03
I04
I05
I06
I07
J01
J02
J03
J04
J05
J06
J07
J08
J09
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Action Type
Coal Mining: Equipment replacement and upgrade
Coal Mining: Pre-mining degasification
Coal Mining: Gas recovery using in-mine horizontal boreholes
Coal Mining: Gas recovery using gob wells
Coal Mining: Recovery of mine ventilation air
Coal Mining: Gas recovery from inactive mines
Coal Mining: Other methane emissions avoidance or recovery
Other projects reducing methane emissions from oil and
natural gas systems and coal mining
General carbon sequestration
General tree planting
Afforestation
Reforestation
Urban Forestry (sequestration effects only)
Forest preservation
Modified forest management
Woody biomass production and other agroforestry
Wood products
Conservation tillage
Other carbon sequestration projects/activities
General halogenated substances
Reclamation: Recycling
Reclamation: Destruction
Substitution
Emission avoidance
Use of improved appliances
Other halogenated substances projects/activities
General projects
Other materials recycling/reuse
Waste/source reduction
Coal ash reuse
Underground injection of carbon dioxide
Reduction of process emissions
Research and development programs
Education and training programs
All other projects not included in the above categories
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Expiration Date: TBD
Voluntary Reporting of Greenhouse Gases
Appendix N. Emission Factors for Steam and
Chilled/Hot Water
Emission Factors for Steam and Chilled/Hot Water for Emissions Inventories
Use the emission factors in the following table to calculate indirect emissions from the consumption of
purchased steam and hot/chilled water for emissions inventories.
Energy Product
Steam or Hot Water
Units of Measure
Value a
Chilled Water
Units of Measure
Absorption Chiller Using Natural Gas b
Engine-Driven Chiller Using Natural Gas b
Electric-Driven Chiller b
Units of Measure
Domestic
1999-2002c
1991-1994c
Foreign
Carbon Dioxide
Methane
Nitrous Oxide
kg/MMBtu
88.18
g/MMBtu
8.169
g/MMBtu
0.603
kg/ton-hours
cooling
0.884
0.590
g/ton-hours
cooling
0.083
0.056
g/ton-hours
cooling
0.002
0.001
kg/ton-hours
cooling
g/ton-hours
cooling
g/ton-hours
cooling
0.629
0.639
0.017
0.019
0.010
0.011
See Note 2 below
See Note 2 below
See Note 2 below
a
Weighted average based on U.S. Energy Information Administration’s (EIA) 1998 Manufacturers Energy Consumption Survey data
on the quantities of natural gas, coal, and residual and distillate fuel oils consumed as boiler fuel, emission factors from Appendix H
of these instructions, and EIA/OIAF efficiency assumptions of 80, 81, and 82 percent for natural gas, coal and petroleum boilers,
respectively. Factors also assume 10 percent losses during transmission.
b
Chilled water efficiencies based on California Climate Action Registry, General Reporting Protocol (October 2002). Factors also
assume 10 percent losses during transmission.
c
Use 1999-2002 factors to calculate emissions and reductions for Start Year reports for 2002 or later and Reporting Year reports for
2003 or later. Use 1991-1994 factors to calculate emissions and reductions for Start Year reports for 1990 through 2001 and
Reporting Year reports for 1991 through 2002. Factors also assume 10 percent losses during transmission.
Emission Factors for Steam and Chilled/Hot Water for Emission Reductions
Use the emission factors in the table below to calculate the following:
• Avoided emissions resulting from the sale of steam and hot/chilled water to another entity.
• Reductions in indirect emissions resulting from the consumption of purchased steam and
hot/chilled water.
Energy Product
Steam or Hot Water (kg CO2e/MMBtu)
Chilled Water (kg CO2e/ton-hours cooling)
Absorption Chiller Using Natural Gas c
Engine-Driven Chiller Using Natural Gas c
Electric-Driven Chiller c
Domestic
1999-2002d
1991-1994d
Foreign
Avoided Emissions
From Energy Sales
79.71a
Reductions in Indirect
Emissions From
Purchased Energy
88.57b
0.884
0.590
0.754e
0.754e
See note 2 below
0.892
0.918
See note 2 below
a
Weighted average based on U.S. Energy Information Administration’s (EIA) 1998 Manufacturers Energy Consumption Survey data
on the quantities of natural gas, coal, and residual and distillate fuel oils consumed as boiler fuel, emission factors from Appendix H
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of these instructions, and EIA/OIAF efficiency assumptions of 80, 81, and 82 percent for natural gas, coal and petroleum boilers,
respectively.
b
Same methodology as avoided emission reductions factors but includes 10 percent losses during transmission.
c
Chilled water efficiencies based on California Climate Action Registry, General Reporting Protocol (October 2002).
d
Use 1999-2002 factors to calculate emissions and reductions for Start Year reports for 2002 or later and Reporting Year reports for
2003 or later. Use 1991-1994 factors to calculate emissions and reductions for Start Year reports for 1990 through 2001 and
Reporting Year reports for 1991 through 2002.
e
All avoided emission reductions are assumed to displace chilled water from electric driven chillers.
Source: U.S. Department of Energy, Office of Policy and International Affairs, Technical Guidelines to the Voluntary Reporting of
Greenhouse Gases (1605(b)) Program (March 2006) p. 154-156.
Note 1 – Calculation Methods
Steam or Hot Water Emission Factors
Steam and hot water emission factors were calculated using the following equations:
EFInventories = EFf * CE * 1/(1-TL)
EFReductions = EFf * CE * 1/(1-TL)
EFAvoided Emissions = EFf * CE
Where:
EFInventories
=
EFReductions
EFAvoided Emissions
EFf
=
=
=
CE
TL
=
=
Emission factor for emissions inventories (kg CO2/MMBtu, g
CH4/MMBtu, or g N2O/MMBtu)
Emission factor for emission reductions (kg CO2e/MMBtu)
Emission factor for avoided emissions (kg CO2e/MMBtu)
Emission factor for boiler fuel used (kg CO2/MMBtu, kg
CO2e/MMBtu, g CH4/MMBtu, or g N2O/MMBtu)
Conversion efficiency of boiler (percent)
Transmission losses (percent)
Chilled Water Emission Factors
Emission factors for chilled water from absorption or engine-driven chillers were calculated using the
following equations:
EFInventories = EFf * ECF * COP * 1/(1-TL)
EFReduction = EFf * ECF * COP * 1/(1-TL)
EFAvoided Emissions = EFf * ECF * COP
Where:
EFInventories
=
EFReductions
EFAvoided Emissions
EFf
=
=
=
ECF
COP
TL
=
=
=
Emission factor for emissions inventories (kg CO2/ton hour cooling,
g CH4/ton hour cooling, or g N2O/ton hour cooling)
Emission factor for emission reductions (kg CO2e/ton hour cooling)
Emission factor for avoided emissions (kg CO2e/ton hour cooling)
Emission factor for boiler fuel used (kg CO2/MMBtu, kg
CO2e/MMBtu, g CH4/MMBtu, or g N2O/MMBtu)
Energy conversion factor (9.7024 x 10-4 MMBtu/ton hours cooling)
Coefficient of performance (dimensionless)
Transmission losses (percent)
Emission factors for chilled water from electric-driven chillers were calculated using the following
equations:
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EFInventories = EFei * ECF * COP * 1/(1-TL)
EFReduction = EFer * ECF * COP * 1/(1-TL)
EFAvoided Emissions = EFea * ECF * COP
Where:
EFInventories
=
EFReductions
EFAvoided Emissions
EFei
=
=
=
EFer
=
EFea
=
ECF
COP
TL
=
=
=
Emission factor for emissions inventories (kg CO2/ton hour cooling,
g CH4/ton hour cooling, or g N2O/ton hour cooling)
Emission factor for emission reductions (kg CO2e/ton hour cooling)
Emission factor for avoided emissions (kg CO2e/ton hour cooling)
U.S. average or regional or national foreign emission factor for
electricity for emission inventories (metric tons CO2/MWh, kg
CH4/MWh, or kg N2O/MWh) 12
U.S. average or regional or national foreign emission factor for
electricity for emission reductions (metric tons CO2e/MWh) 13
U.S. average or regional or national foreign emission factor for
electricity for avoided emissions (metric tons CO2e/MWh) 14
Energy conversion factor (3.51685 x 10-3 MWh/ton hours cooling)
Coefficient of performance (dimensionless)
Transmission losses (percent)
Note 2 – Electric Driven Chiller Emission Factors for Foreign Countries
For emissions and emission reductions associated with electric-driven chillers in foreign countries,
reporters should calculate emission factors using the regional or national foreign electricity emission
factors in Appendix F. Use the formulas provided below, which are based on the methods described in
Note 1 above, to calculate appropriate emission factors (kg/ton-hour cooling).
Chilled Water Emission Factor for Use in Calculating Indirect Emissions for Emission Inventories
Reporters should use the following formula for calculating appropriate CO2, CH4, and N2O emissions
factors for use in estimating indirect emissions for emissions inventories:
EF Chilled Water = 0.921 * EF Electric/Inventory
Where:
EF Chilled Water
=
EF Electric/Inventory =
Emissions factor, expressed in kg CO2/ton hour, g CH4/ton hour, or
g N2O/ton hour of cooling purchased
Appropriate regional or national electricity emissions factor for
emission inventory from Appendix F, expressed in MT CO2/MWh, kg
CH4/ton hour, or kg N2O/ton hour of cooling purchased
The resulting emission factors assume 10 percent losses during transmission. Calculate separate emission
factors for CO2, CH4, and N2O.
12
Electricity emission factors were taken from Appendix F of the instructions to Form EIA-1605 and multiplied by
1000 to convert the units from metric tons per MWh to kilograms per MWh for carbon dioxide and from kilograms
per MWh to grams per MWh for methane and nitrous oxide.
13
Electricity emission factors were taken from Appendix F of the instructions to Form EIA-1605 and multiplied by
1000 to convert the units from metric tons CO2e per MWh to kilograms CO2e per MWh.
14
Electricity emission factors were taken from Appendix F of the instructions to Form EIA-1605 and multiplied by
1000 to convert the units from metric tons CO2e per MWh to kilograms CO2e per MWh.
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Chilled Water Emission Factor for Use in Calculating Reductions in Indirect Emission Reductions
Reporters should use the following formula for calculating an appropriate emissions factor for use in
estimating reductions in indirect emission associated with purchased chilled water:
EF Chilled Water = 0.921 * EF Electric/Indirect
Where:
EF Chilled Water
=
EF Electric/Indirect =
Emissions factor, expressed in kg CO2e/ton hour of cooling
purchased
Appropriate regional electricity emissions factor for indirect
emission reductions from Appendix F, expressed in MT CO2e/MWh.
The resulting emission factors assume 10 percent losses during transmission.
Chilled Water Emission Factor for Use in Calculating Avoided Emissions
Reporters should use the following formula for calculating an appropriate emissions factor for use in
estimating avoided emissions associated with the sale of chilled water produced by electric-driven chillers
to other entities:
EF Chilled Water = 0.837 * EF Electric/Indirect
Where:
EF Chilled Water
=
EF Electric/Indirect =
Emissions factor, expressed in kg CO2e/ton hour of cooling
purchased
Appropriate regional or national emission electricity emissions
factor for indirect emission reductions from Appendix F, expressed
in MT CO2e/MWh.
The resulting emission factor assumes no losses during transmission.
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Glossary of Selected Terms
Activity of a small emitter: With respect to a small emitter, any single category of anthropogenic
production, consumption or other action that releases emissions or results in sequestration, the annual
changes of which can be assessed generally by using a single calculation method.
Afforestation: The establishment of forest or forest stands on lands that have not been recently forested.
Aggregator: An entity that reports to the 1605(b) program on behalf of non-reporting entities. An
aggregator may be a large or small emitter, such as a trade association, non-profit organization or public
agency.
Agroforestry: A land-use system that involves deliberate retention, introduction, or mixture of trees or
other woody perennials in crop and animal production systems to take advantage of economic and/or
ecological interactions among the components.
Anaerobic lagoon: A liquid-based organic waste management installation characterized by waste
residing in water at a depth of at least 6 feet for periods of 30 to 200 days.
Anaerobic decomposition: Decomposition in the absence of oxygen, as in an anaerobic lagoon or
digester, which produces CO2 and CH4.
Anthropogenic: Greenhouse gas emissions and removals that are a direct result of human activities or are
the result of natural processes that have been affected by human activities.
Avoided emissions: The greenhouse gas emission reductions that occur outside the organizational
boundary of the entity as a direct consequence of changes in the entity’s activity, including but not
necessarily limited to the emission reductions associated with increases in the generation and sale of
electricity, steam, hot water or chilled water produced from energy sources that emit fewer greenhouse
gases per unit than other competing sources of these forms of distributed energy.
Base period: A period of 1-4 years used to derive the average annual base emissions, emissions intensity
or other values from which emission reductions are calculated.
Base value: The value from which emission reductions are calculated for an entity or subentity. The
value may be annual emissions, emissions intensity, kilowatt-hours generated, or other value specified in
the 1605(b) guidelines. It is usually derived from actual emissions and/or activity data derived from the
base period.
Biofuels: Liquid fuels and blending components produced from biomass (plant) feedstocks, used
primarily for transportation.
Biogenic emissions: Emissions that are naturally occurring and are not significantly affected by human
actions or activity.
Biomass: Non-fossilized organic matter available on a renewable basis, including organic material (both
living and dead) from above and below ground, e.g., trees, crops, grasses, tree litter, roots, animals, and
animal waste. Biomass includes forest and mill residues, agricultural crops and residues, wood and wood
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residues, animal wastes, livestock operation residues, aquatic plants, fast-growing trees and plants, and
the organic portion of municipal and relevant industrial wastes.
Boundary: The actual or virtual line that encompasses all the emissions and carbon stocks that are to be
quantified and reported in an entity's greenhouse gas inventory, including de minimis emissions. Entities
may use financial control or another classification method based on ownership or control as the means of
determining which sources or carbon stocks fall within this organizational boundary.
Calcining: The process of thermally decomposing carbonate into quicklime, as in cement manufacturing.
Carbon cycle: The flow of carbon through the atmosphere, ocean, terrestrial biosphere, and lithosphere.
Carbon exchange between carbon pools is driven by chemical, physical, geological, and biological
processes. Also see Carbon pool below.
Carbon dioxide equivalent (CO2e): The amount of carbon dioxide by weight emitted into the
atmosphere that would produce the same estimated radiative forcing as a given weight of another
radiatively active gas. Carbon dioxide equivalents are computed by multiplying the weight of the gas
being measured (for example, methane) by its estimated global warming potential. The global warming
potential (GWP) is the standard unit used for aggregating different greenhouse gases with dissimilar
radiative forcing properties into a common unit. Also see Global warming potential below
Carbon flow/carbon flux: The movement of carbon from one carbon pool to another, expressed as a
quantum transfer (flow), or as a rate per unit time (flux).
Carbon pool: Any reservoir of carbon. The four pools are atmosphere, biosphere, oceans and sediments.
Carbon stocks: The quantity of carbon stored in biological and physical systems including: trees,
products of harvested trees, agricultural crops, plants, wood and paper products and other terrestrial
biosphere sinks, soils, oceans, and sedimentary and geological sinks.
Chlorofluorocarbon (CFC): Any of the various compounds of carbon, hydrogen, chlorine, and fluorine,
typically used as refrigerants and for other purposes.
Climate Leaders: The EPA sponsored industry-government partnership that works with individual
companies to develop long-term comprehensive climate change strategies. Certain Climate Leaders
Partners have, working with EPA, set a corporate-wide greenhouse gas reduction goal and have
inventoried their emissions to measure progress towards their goal.
Climate VISION: The public-private partnership initiated pursuant to a Presidential directive issued in
2002 that aims to contribute to the President's goal of reducing greenhouse gas intensity through
voluntary frameworks with industry. Climate VISION partners have signed an agreement with DOE to
implement various climate-related actions to reduce greenhouse gas emissions.
Cogeneration facility: A facility producing electricity and another form of useful energy (such as heat or
steam) through sequential use of energy.
Coke: The solid black hydrocarbon left as a residual after the volatile hydrocarbons have been removed
from bitumen by distillation. It is a fuel product often used in metal processing as a fuel and a reduction
agent for oxide compounds, the use of which results in carbon dioxide emissions.
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Conversion factor: A coefficient that converts units of one measurement system into corresponding units
in another measurement system.
Cropland: A land cover/use category that includes areas used for the production of crops for harvest.
De minimis emissions: Emissions from one or more sources and of one or more greenhouse gases that, in
aggregate, are less than or equal to 3 percent of the total annual carbon dioxide (CO2) equivalent
emissions of an entity.
DOE: The U. S. Department of Energy.
Direct emissions: Emissions from sources within the organizational boundaries of an entity.
Direct measurement: Quantification of the greenhouse gas components of an exhaust stream by
continuous emissions monitoring (CEM) or sufficient periodic sampling to closely approximate
continuous monitoring.
Direct monitoring: See Direct measurement
Distributed energy: Electrical or thermal energy generated by an entity that is sold or otherwise
exported outside of the entity’s boundaries for use by another entity.
Double reporting: When one entity submits emission or reduction data more than once or when two or
more entities report the same emission or reduction.
Ecosystem carbon components:
Live tree – A living woody perennial plant (capable of reaching at least 15 feet in height) with a
diameter at breast height greater than 2.5 cm (1 inch), including the carbon mass in roots with
diameters greater than 0.2 to 0.5 cm (note the specific diameter threshold will depend on
sampling/estimation methods), stems, branches, and foliage.
Tree seedling – A trees less than 2.5 cm (1 inch) diameter at breast height.
Standing dead tree – A dead tree of at least 2.5 cm diameter at breast height that has not yet fallen,
including the carbon mass of coarse roots, stems, and branches.
Understory vegetation – Roots, stems, branches, and foliage of tree seedlings, shrubs, herbs, forbs,
and grasses.
Forest floor – Fine woody debris (smaller than 7.5 cm), tree litter, humus, and fine roots in the
organic forest floor layer above mineral soil.
Down dead wood – Logging residue and other coarse dead wood on the ground (greater than 7.5
cm diameter), as well as stumps and the coarse roots of stumps.
Soil – Includes fine roots and all other organic carbon not included in the above pools, to a depth of
one (1) meter.
Harvested wood – Wood removed from the forest ecosystem for the processing of various products.
Logging debris (slash) left in the forest after harvesting is not included.
EIA: The U.S. Energy Information Administration within the U.S. Department of Energy.
Emissions: The direct release of greenhouse gases to the atmosphere from any anthropogenic (human
induced) source and certain indirect emissions (releases) specified in this part.
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Emissions coefficient: A unique value for scaling emissions to activity data in terms of a standard rate of
emissions per unit of activity (e.g., pounds of carbon dioxide emitted per Btu of fossil fuel consumed).
Emissions factor: see Emissions coefficient
Emissions, fugitive: Any unintentional release of greenhouse gases to the atmosphere, including methane
from the processing, transmission, and/or transportation of fossil fuels, HFCs from stationary and mobile
air-conditioning and refrigeration equipment, SF6 from electric power distribution, and methane from
solid waste landfills.
Emissions intensity: Emissions per unit of output, where output is defined as the quantity of physical
output, or a non-physical indicator of an entity's or subentity's productive activity.
Emissions, process: Emissions inherent in a productive process, as in cement or ammonia manufacture,
as distinguished from those resulting from fuel combustion.
Emissions source: A discrete process, occurring at a particular location, which emits one or more
Greenhouse Gases.
Engineered sequestration: An engineered process whereby carbon dioxide is captured from the point of
emission and then stored in underground reservoirs (geologic sequestration), dissolved in deep oceans, or
converted to rock-like solid materials.
Enteric fermentation: Animal digestion aided by methane-generating microbes in the animal rumen and
intestine that produces greenhouse gas emissions, primarily methane.
Entity: The whole or part of any business, institution, organization, government agency or corporation, or
household that:
• Is recognized under any U.S. Federal, State or local law that applies to it;
• Is located and operates, at least in part, in the United States; and
• The emissions of such operations are released, at least in part, in the United States.
A reporting entity is an entity that has submitted a report under the 1605(b) program that has been
accepted by the U.S. Energy Information Administration.
Entity boundary: The limit in the scope of coverage for an entity’s emission inventory and emission
reduction report.
Entity statement: The 1605(b) participant’s description of entity name, primary activities, covered sites
and activities, emissions measurement method(s) and the applicability of each method to separate
operations. In the case of entities seeking to register emission reductions, the entity statement also
provides information on the methods used to define the operational boundaries of the entity and the
resulting entity boundaries, shared ownership arrangements, designation of a start year, description of
baseline methods, and identification of sub-entities to which different measurement methods may apply.
For more specific requirements of entity statements, see § 300.5 of 10 CFR Part 300, Guidelines for
Voluntary Greenhouse Gas Reporting.
Equity share: The percentage interest in ownership, benefits, or control that may govern entitlements to
emission reductions by participants in collective undertakings.
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Estimation method: The technique, including key assumptions and data sources, used by a 1605(b)
participant to derive reported emissions, emission reductions, and/or sequestration where actual
measurement is not possible or practical.
Financial control: The ability to direct the financial and operating policies of all elements of the entity
with a view to gaining economic or other benefits from its activities over a period of many years.
First reduction year: The first year for which an entity intends to register emission reductions; it is the
year that immediately follows the start year.
Flaring: The combustion of non-utilized gases prior to release into the atmosphere. See also Venting.
Forest land: Land at least 10 percent stocked by forest trees of any size, or formerly having such tree
cover, and not currently developed for non-forest uses. The minimum area considered for classification is
one (1) acre.
Forest management: The practical application of biological, physical, quantitative, managerial,
economic, social, and policy principles to the regeneration, tending, protection, harvest, access,
utilization, and conservation of forests to meet specified goals and objectives while maintaining the
productivity of the forest.
Fugitive emissions: Uncontrolled releases to the atmosphere of greenhouse gases from the processing,
transmission, and/or transportation of fossil fuels or other materials, such as HFC leaks from refrigeration,
SF6 from electrical power distributors, and methane from solid waste landfills, among others, that are not
emitted via an exhaust pipe(s) or stack(s).
General Guidelines: The emission and emission reduction Guidelines that appear in Part 300 of the U.S.
Code of Federal Regulations.
Geologic sequestration: A type of engineered sequestration, where captured carbon dioxide is injected
for permanent storage into underground geologic reservoirs, such as oil and natural gas fields, saline
aquifers, or abandoned coal mines.
Global warming potential (GWP): An index used to compare the relative radiative forcing of different
gases without directly calculating the changes in atmospheric concentrations. GWPs are calculated as the
ratio of the radiative forcing that would result from the emission of one kilogram of a greenhouse gas to
that from the emission of one kilogram of carbon dioxide over a fixed period of time, such as 100 years.
Grassland: Rangelands and pasturelands that are not considered cropland and would not become
forestland without human intervention.
Greenhouse gases (GHGs): The gases that may be reported to the Department of Energy under this
program. They are:
(1) Carbon dioxide (CO2)
(2) Methane (CH4)
(3) Nitrous oxide (N2O)
(4) HydrofluorocarbonsHFC-23 [trifluoromethane- (CHF3]HFC-32 [trifluoromethane-CH2F2],
CH2CF3, CH3F, CHF2CF3, CH2FCF3, CH3FCF3, CHF2CH2F, CF3CH3, CH2FCH2F, CH3CHF2,
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CH3CH2F, CF3CHFCF3, CH2FCF2CF3, CHF2CHFCF3, CF3CH2CF3, CH2FCF2CHF2,
CHF2CH2CF3, CF3CH2CF2CH3, CH3 CHFCHFCF2)
(5) Perfluorocarbons (perfluoromethane-CF4, perfluoroethane-C2F6, C3F8, C4F10, c-C4F8, C5F12,
C6F14)
(6) Sulfur hexafluoride (SF6 )
(7) Chlorofluorocarbons (CFC-11 [trichlorofluoromethane-CCl3F], CCl2F2, CClF3, CCl2FCClF2,
CClF2CClF2, ClF3CClF2,)
(8) Other gases or particles that have been demonstrated to have significant, quantifiable climate
forcing effects when released to the atmosphere in significant quantities and for which DOE has
established or approved methods for estimating emissions and reductions. (Note: As provided in §
300.6(i) of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting,
chlorofluorcarbons and other gases with quantifiable climate forcing effects may be reported to
the 1605(b) program if DOE has established an appropriate emission inventory or emission
reduction calculation method, but reductions of these gases may not be registered.)
Heating value: The amount of thermal energy released per unit of a fuel that is burned completely.
Hydrofluorocarbons (HFCs): A class of anthropogenically created chemical compounds composed of
one or more carbon atoms and varying numbers of hydrogen and fluorine atoms. Most HFCs have potent
radiative forcing effects, with 100-year GWPs generally between 1,300 and 12,000 times that of CO2.
Incidental lands: Entity landholdings that are a minor component of an entity’s operations and are not
actively managed for production of goods and services, including:
(1)Transmission, pipeline, or transportation right of ways that are not managed for timber
production;
(2) Land surrounding commercial enterprises or facilities; and
(3) Land where carbon stock changes are determined by natural factors.
Independent verifier: One who is qualified to attest to the accuracy and completeness of emissions
reports and who is capable of independent assessment by virtue of having no ties to the emitter that might
create a conflict of interest. For detailed qualifications of independent verifiers, see § 300.11 of 10 CFR
Part 300, Guidelines for Voluntary Greenhouse Gas Reporting.
Independent verification: A process by which an organizationally independent source assess the
accuracy, completeness and conformity with DOE Guidelines of proffered entity reports of emissions and
emission reductions, in accord with 1605(b) Guidelines. For detailed qualifications of independent
verification, see § 300.11 of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas Reporting.
Indexed measure: An output measure, either physical or economic, that is defined relative to an index
year’s physical quantity or dollar value.
Indirect emissions: Greenhouse gas emissions from stationary or mobile sources outside the
organizational boundary that occur as a direct consequence of an entity’s activity, including but not
necessarily limited to the emissions associated with the generation of electricity, steam and hot/chilled
water used by the entity.
Intergovernmental Panel on Climate Change (IPCC): A panel established jointly by the World
Meteorological Organization and the United Nations Environmental Program in 1988 to assess scientific,
technical and socio-economic information relevant to climate change, its potential impacts, and options
for adaptation and mitigation.
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Inventory: A quantified account of an entity’s total Greenhouse Gas emissions.
Joint venture: A legal organization that takes the form of a partnership in which the persons jointly
undertake a transaction for mutual profit. Generally each person contributes assets and share risks. Like a
partnership, joint ventures can involve any type of business transaction and the “persons” involved can be
individuals, groups of individuals, companies, or corporations. (Source:
http://www.law.cornell.edu/wex/index.php/Joint_venture.)
Landfill gas: Gas that is generated by the decomposition of organic material at landfill disposal sites. The
average composition of landfill gas is approximately 50 percent methane and 50 percent carbon dioxide
and water vapor by volume. The methane percentage, however, can vary from 40 to 60 percent,
depending on several factors including waste composition (e.g. carbohydrate and cellulose content). The
methane in landfill gas may be vented, flared, combusted to generate electricity or useful thermal energy
on-site, or injected into a pipeline for combustion off-site.
Large emitter: an entity whose annual emissions are more than 10,000 metric tons of CO2 equivalent, as
determined in accordance with § 300.5(c) of 10 CFR Part 300, Guidelines for Voluntary Greenhouse Gas
Reporting.
Life cycle: The progression of a product or facility through its service life.
Look-up tables: Reference tables, typically provided to relate values of an observable parameter to
corresponding values of less easily observed variables.
Managed carbon stocks: Stocks that are affected by human decision or action. Examples include
managed forest, engineered carbon sinks, or certain agricultural practices.
Mass balance: A method for calculating emissions based on the mass and composition of fuel inputs,
appropriate emissions factors, and combustion performance.
Materials balance calculation: A computation of carbon flow through an industrial process.
Mineral soils: A soil consisting predominantly of, and having its properties determined predominantly
by, mineral matter. Usually contains less than 200 g / kg organic carbon (less than 120-180 g / kg if
saturated with water), but may contain an organic surface layer up to 30 cm thick.
Mobile source emissions: Transportation emissions, plus emissions from small engines such as
lawnmowers and equipment used at commercial and industrial sites, non-road equipment used in farming
and forestry, at airports, and at railroad and marine terminals.
Municipal solid waste: Residential solid waste and some non-hazardous commercial, institutional, and
industrial wastes.
Natural disturbances: Processes or events such as insect outbreaks, fire, disease, flooding, windstorms
and avalanches that cause ecosystem change.
Net carbon flow: The sum of all transfers of carbon between the land and the atmosphere over a
specified period. See also Carbon flow/carbon flux.
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Voluntary Reporting of Greenhouse Gases
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Net emission reductions or net entity-wide emission reductions: The sum of all annual changes in
emissions, eligible avoided emissions and sequestration of the greenhouse gases specifically identified in
§ 300.6(i), and determined to be in conformance with §§ 300.7 and 300.8 of 10 CFR Part 300, Guidelines
for Voluntary Greenhouse Gas Reporting.
Offset: An emission reduction that is included in a 1605(b) report and meets the requirements of 10 CFR
Part 300, Guidelines for Voluntary Greenhouse Gas Reporting, but is achieved by an entity other than the
reporting entity. Offset reductions must not be reported or registered by any other entity and must appear
as a separate and distinct component of an entity’s report. Offsets are not integrated into the reporting
entity’s emissions or net emission reductions.
Operational control: The authority to introduce and implement operating policies in an organization.
Operations data system: A data collection system that reports the physical quantities of inputs utilized
and products manufactured. These data are typically produced for management and regulatory
compliance needs and are usually held at the facility level in the organization.
Organic growth/decline: Increases/decreases in greenhouse gas emissions as a result of changes in
production levels, net investment in new capacity, and changes in product mix, as distinguished from
acquisitions and divestitures.
Organic soils: Soil materials that are saturated with water and have 174 g / kg or more organic carbon if
the mineral fraction has 500 g / kg or more clay, or 116 g / kg organic carbon if the mineral fraction has
no clay, or has proportional intermediate contents. If these materials were never saturated with water they
would have 203 g / kg or more organic carbon.
Organizational boundary: The scope of the entity covered by 1605(b) reporting, as defined in the entity
statement. Generally, the organizational boundary of an entity encompasses all facilities and operations
that are under the management control of the entity, which usually includes all land, facilities and vehicles
that are wholly or majority owned or under long-term lease by the entity, as well as certain other facilities,
vehicles or land that are under the management control of the entity. See also Entity Boundary.
Output: Output is a physical or economic measure used in determining an entity’s or subentity’s
emissions intensity that is a reliable indicator of the level of activity of the entity or subentity and is
related to the emissions levels of the entity or subentity.
Outsourcing: Contracting out activities by an entity to other businesses, where the output of the
outsourced activity is later re-integrated into the entity’s products or is otherwise integral to the entity’s
operations.
Permanence: The longevity of carbon in a carbon sink (such as forest land).
Perfluorocarbons (PFCs): A group of man-made chemicals composed of one or six carbon atoms and
four to fourteen fluorine atoms, containing no chlorine. PFCs are compounds derived from hydrocarbons
by replacement of hydrogen atoms by fluorine atoms. PFCs have several commercial uses and are emitted
as a byproduct of aluminum smelting and semiconductor manufacturing. PFCs have very high 100-year
Global Warming Potentials and are very long-lived in the atmosphere.
Prescribed fire: Intentionally set and managed forest burns, which further specific resource management
objectives.
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
OMB No. 1905-0194
Expiration Date: TBD
Process emissions: See Emissions, process.
Process models: Mathematical representations of ecosystem processes, such as nitrogen and carbon
cycles.
Reforestation: The re-establishment of forest cover, naturally or artificially, on lands that have recently
been harvested or otherwise cleared of trees.
Regeneration: The natural (by natural seeding, coppice, or root suckers) or artificial (by direct seeding or
planting) process of re-establishing tree cover on forestland.
Registration: The reporting of emission reductions that the EIA has determined meet the qualifications
for registered emission reductions set forth in the guidelines.
Reporting but not registering: If an entity does not choose to report emissions in a manner that
conforms to the registration requirements, including those set forth in §§ 300.6 and 300.7 of 10 CFR Part
300, Guidelines for Voluntary Greenhouse Gas Reporting, then the entity may choose to report on any
emissions or any emission reductions by complying with the other requirements of 10 CFR Part 300.
Reporting Year: The year that is the subject of a report to EIA.
Sequestration: The process by which CO2 is removed from the atmosphere, either through biologic
processes or physical processes.
Simplified Emission Inventory Tool (SEIT): A computer-based method, to be developed and made
readily accessible by EIA, for translating common physical indicators into an estimate of greenhouse gas
emissions.
Silviculture: The art and science of controlling the establishment, growth, composition, health, and
quality of forests and woodlands.
Sink: An identifiable discrete location, set of locations, or area in which CO2 or some other greenhouse
gas is sequestered.
Small emitter: An entity whose annual emissions are less than or equal to 10,000 metric tons of CO2
equivalent, as determined in accordance with § 300.5(c), and that chooses to be treated as a small emitter
under the guidelines.
Source: Any land, facility, process, vehicle or activity that releases a greenhouse gas.
Start year: The year upon which the initial entity statement is based and the last year of the initial base
period(s).
Stationary sources: Emission sources at fixed locations, such as power plants, factories, refineries,
mines, heating plants or waste conversion facilities.
Subentity: A component of any entity, such as a discrete business line, facility, plant, vehicle fleet, or
energy using system, which has associated with it emissions of greenhouse gases that can be
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Form EIA-1605
Voluntary Reporting of Greenhouse Gases
Form Approved
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Expiration Date: TBD
distinguished from the emissions of all other components of the same entity and, when summed with the
emissions of all other subentities, equal the entity's total emissions.
Sustainable Forest Management: The practice of managing forests to provide ecological, economic,
social and cultural benefits for present and future generations. For the purposes of 1605(b) reporting, a
determination of sustainably managed forests must be certified consistent with provisions of the
Technical Guidelines, Chapter 1.I.3.5.
Technical Guidelines: Detailed explanatory supplements to the 1605(b) General Guidelines.
Terrestrial sequestration: Biotic sequestration of carbon in above- and below-ground biomass and soils.
Total emissions: The total annual contribution of the greenhouse gases (as defined in 10 CFR Part 300,
Guidelines for Voluntary Greenhouse Gas Reporting) to the atmosphere by an entity, including both
direct and indirect entity-wide emissions.
Total entity-wide emission reductions: The sum of all annual changes in emissions, carbon stocks and
avoided emissions of the greenhouse gases specifically identified in §300.6(f) 10 CFR Part 300,
Guidelines for Voluntary Greenhouse Gas Reporting, determined in conformance with §300.7 and 300.8
of those guidelines. In calculating this total, decreases in emissions and increases in carbon stocks and
avoided emissions are expressed as positive values.
Transportation sources: In the context of emissions, transportation sources include vehicles that operate
on roads and highways, as well as non-road vehicles, engines, and equipment, but exclude farm
equipment associated with particular farm premises. Examples of transportation sources include cars,
trucks, buses, earth-moving equipment, lawn and garden power tools, ships, railroad locomotives, and
airplanes.
United States or U.S.: The 50 States, the District of Columbia, the Commonwealth of Puerto Rico, the
Commonwealth of the Northern Mariana Islands, Guam, American Samoa, and any other territory of the
United States.
Venting: Release of gases into the atmosphere without combustion. See also Flaring.
Verification: See Independent verification.
Wood products: Products derived from the harvested wood from a forest, including fuel-wood and logs
and the products derived from them such as cut timber, plywood, wood pulp, paper, etc. Includes both
products in use and in disposal systems such as landfills (but which have not yet decayed, releasing
carbon to the atmosphere as carbon dioxide and/or methane).
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| File Type | application/pdf |
| File Title | Voluntary Reporting of |
| Author | Dick Richards |
| File Modified | 2010-07-28 |
| File Created | 2010-07-28 |