[Federal Register Volume 78, Number 63 (Tuesday, April 2, 2013)]
[Proposed Rules]
[Pages 19802-19877]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2013-06093]
[[Page 19801]]
Vol. 78
Tuesday,
No. 63
April 2, 2013
Part II
Environmental Protection Agency
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40 CFR Part 98
2013 Revisions to the Greenhouse Gas Reporting Rule and Proposed
Confidentiality Determinations for New or Substantially Revised Data
Elements; Proposed Rule
Federal Register / Vol. 78 , No. 63 / Tuesday, April 2, 2013 /
Proposed Rules
[[Page 19802]]
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ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 98
[EPA-HQ-OAR-2012-0934; FRL-9789-1]
RIN 2060-AR52
2013 Revisions to the Greenhouse Gas Reporting Rule and Proposed
Confidentiality Determinations for New or Substantially Revised Data
Elements
AGENCY: Environmental Protection Agency (EPA).
ACTION: Proposed rule.
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SUMMARY: The EPA is proposing to amend the Greenhouse Gas Reporting
Rule and to clarify or change specific provisions. Particularly, the
EPA is proposing to amend a table in the General Provisions, to reflect
revised global warming potentials of some greenhouse gases that have
been published by the Intergovernmental Panel on Climate Change and to
add global warming potentials for certain fluorinated greenhouse gases
not currently listed in the table. This action also proposes
confidentiality determinations for the reporting of new or
substantially revised (i.e., requiring additional or different data to
be reported) data elements contained in these proposed amendments to
the Greenhouse Gas Reporting Rule.
DATES: Comments. Comments must be received on or before May 17, 2013.
Public Hearing. The EPA does not plan to conduct a public hearing
unless requested. To request a hearing, please contact the person
listed in the FOR FURTHER INFORMATION CONTACT section of this preamble
by April 9, 2013. If requested, the hearing will be conducted on April
17, 2013, in the Washington, DC area. The EPA will provide further
information about the hearing on its Web page if a hearing is
requested.
ADDRESSES: You may submit your comments, identified by Docket ID No.
EPA-HQ-OAR-2012-0934 by any of the following methods:
Federal eRulemaking Portal: http://www.regulations.gov.
Follow the online instructions for submitting comments.
Email: [email protected]. Include Docket ID No.
EPA-HQ-OAR-2012-0934 or RIN No. 2060-AR52 in the subject line of the
message.
Fax: (202) 566-1741.
Mail: Environmental Protection Agency, EPA Docket Center
(EPA/DC), Mailcode 6102T, Attention Docket ID No. EPA-HQ-OAR-2012-0934,
1200 Pennsylvania Avenue NW., Washington, DC 20004.
Hand/Courier Delivery: EPA Docket Center, Public Reading
Room, EPA West Building, Room 3334, 1301 Constitution Avenue NW.,
Washington, DC 20004. Such deliveries are accepted only during the
normal hours of operation of the Docket Center, and special
arrangements should be made for deliveries of boxed information.
Additional Information on Submitting Comments: To expedite review
of your comments by agency staff, you are encouraged to send a separate
copy of your comments, in addition to the copy you submit to the
official docket, to Carole Cook, U.S. EPA, Office of Atmospheric
Programs, Climate Change Division, Mail Code 6207-J, Washington, DC,
20460, telephone (202) 343-9263, email address: [email protected].
Instructions: Direct your comments to Docket ID No. EPA-HQ-OAR-
2012-0934, 2013 Revisions to the Greenhouse Gas Reporting Rule and
Proposed Confidentiality Determinations for New or Substantially
Revised Data Elements. The EPA's policy is that all comments received
will be included in the public docket without change and may be made
available online at http://www.regulations.gov, including any personal
information provided, unless the comment includes information claimed
to be confidential business information (CBI) or other information
whose disclosure is restricted by statute.
Should you choose to submit information that you claim to be CBI,
clearly mark the part or all of the information that you claim to be
CBI. For information that you claim to be CBI in a disk or CD ROM that
you mail to the EPA, mark the outside of the disk or CD ROM as CBI and
then identify electronically within the disk or CD ROM the specific
information that is claimed as CBI. In addition to one complete version
of the comment that includes information claimed as CBI, a copy of the
comment that does not contain the information claimed as CBI must be
submitted for inclusion in the public docket. Information marked as CBI
will not be disclosed except in accordance with procedures set forth in
40 CFR part 2. Send or deliver information identified as CBI to only
the mail or hand/courier delivery address listed above, attention:
Docket ID No. EPA-HQ-OAR-2012-0934. If you have any questions about CBI
or the procedures for claiming CBI, please consult the person
identified in the FOR FURTHER INFORMATION CONTACT section.
Do not submit information that you consider to be CBI or otherwise
protected through http://www.regulations.gov or email. The http://www.regulations.gov Web site is an ``anonymous access'' system, which
means the EPA will not know your identity or contact information unless
you provide it in the body of your comment. If you send an email
comment directly to the EPA without going through http://www.regulations.gov your email address will be automatically captured
and included as part of the comment that is placed in the public docket
and made available on the Internet. If you submit an electronic
comment, the EPA recommends that you include your name and other
contact information in the body of your comment and with any disk or
CD-ROM you submit. If the EPA cannot read your comment due to technical
difficulties and cannot contact you for clarification, the EPA may not
be able to consider your comment. Electronic files should avoid the use
of special characters, any form of encryption, and be free of any
defects or viruses.
Docket: All documents in the docket are listed in the http://www.regulations.gov index. Although listed in the index, some
information is not publicly available, e.g., CBI or other information
whose disclosure is restricted by statute. Certain other material, such
as copyrighted material, will be publicly available only in hard copy.
Publicly available docket materials are available either electronically
in http://www.regulations.gov or in hard copy at the Air Docket, EPA/
DC, EPA West Building, Room 3334, 1301 Constitution Ave. NW.,
Washington, DC. This Docket Facility is open from 8:30 a.m. to 4:30
p.m., Monday through Friday, excluding legal holidays. The telephone
number for the Public Reading Room is (202) 566-1744, and the telephone
number for the Air Docket is (202) 566-1742.
FOR FURTHER INFORMATION CONTACT: Carole Cook, Climate Change Division,
Office of Atmospheric Programs (MC-6207J), Environmental Protection
Agency, 1200 Pennsylvania Ave. NW., Washington, DC 20460; telephone
number: (202) 343-9263; fax number: (202) 343-2342; email address:
[email protected]. For technical information, please go to the
Greenhouse Gas Reporting Rule Program Web site http://www.epa.gov/climatechange/emissions/ghgrulemaking.html. To submit a question,
select Rule Help Center, followed by ``Contact Us.''
Worldwide Web (WWW). In addition to being available in the docket,
an electronic copy of today's proposal will also be available through
the WWW.
[[Page 19803]]
Following the Administrator's signature, a copy of this action will be
posted on EPA's greenhouse gas reporting rule Web site at http://www.epa.gov/climatechange/emissions/ghgrulemaking.html.
SUPPLEMENTARY INFORMATION:
Regulated Entities. The Administrator determined that this action
is subject to the provisions of Clean Air Act (CAA) section 307(d). See
CAA section 307(d)(1)(V) (the provisions of CAA section 307(d) apply to
``such other actions as the Administrator may determine''). These are
proposed amendments to existing regulations. If finalized, these
amended regulations would affect certain owners and operators of
facilities that directly emit greenhouse gases (GHGs) as well as
certain suppliers. Regulated categories and examples of affected
entities include those listed in Table 1 of this preamble.
Table 1--Examples of Affected Entities by Category
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Category NAICS Examples of affected facilities
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General Stationary Fuel Combustion ................................... Facilities operating boilers,
Sources. process heaters, incinerators,
turbines, and internal combustion
engines.
211................................ Extractors of crude petroleum and
natural gas.
321................................ Manufacturers of lumber and wood
products.
322................................ Pulp and paper mills.
325................................ Chemical manufacturers.
324................................ Petroleum refineries, and
manufacturers of coal products.
316, 326, 339...................... Manufacturers of rubber and
miscellaneous plastic products.
331................................ Steel works, blast furnaces.
332................................ Electroplating, plating, polishing,
anodizing, and coloring.
336................................ Manufacturers of motor vehicle
parts and accessories.
221................................ Electric, gas, and sanitary
services.
622................................ Health services.
611................................ Educational services.
Electricity Generation................ 221112............................. Fossil-fuel fired electric
generating units, including units
owned by federal and municipal
governments and units located in
Indian Country.
Acid Gas Injection Projects........... 211111 or 211112................... Projects that inject natural gas
containing CO2 underground.
Adipic Acid Production................ 325199............................. Adipic acid manufacturing
facilities.
Aluminum Production................... 331312............................. Primary Aluminum production
facilities.
Ammonia Manufacturing................. 325311............................. Anhydrous and aqueous ammonia
manufacturing facilities.
Cement Production..................... 327310............................. Portland cement manufacturing
plants.
CO2 Enhanced Oil and Gas Recovery 211................................ Oil and gas extraction projects
Projects. using CO2 enhanced oil and gas
recovery.
Electrical Equipment Use.............. 221121............................. Electric bulk power transmission
and control facilities.
Electrical Equipment Manufacture or 33531.............................. Power transmission and distribution
Refurbishment. switchgear and specialty
transformers manufacturing
facilities.
Electronics Manufacturing............. 334111............................. Microcomputers manufacturing
facilities.
334413............................. Semiconductor, photovoltaic (solid-
state) device manufacturing
facilities.
334419............................. LCD unit screens manufacturing
facilities. MEMS manufacturing
facilities.
Ethanol Production.................... 325193............................. Ethyl alcohol manufacturing
facilities.
Ferroalloy Production................. 331112............................. Ferroalloys manufacturing
facilities.
Fluorinated GHG Production............ 325120............................. Industrial gases manufacturing
facilities.
Food Processing....................... 311611............................. Meat processing facilities.
311411............................. Frozen fruit, juice, and vegetable
manufacturing facilities.
311421............................. Fruit and vegetable canning
facilities.
Glass Production...................... 327211............................. Flat glass manufacturing
facilities.
327213............................. Glass container manufacturing
facilities.
327212............................. Other pressed and blown glass and
glassware manufacturing
facilities.
GS Sites.............................. NA................................. CO2 geologic sequestration
projects.
HFC-22 Production and HFC-23 325120............................. Chlorodifluoromethane manufacturing
Destruction. facilities.
Hydrogen Production................... 325120............................. Hydrogen manufacturing facilities.
Importers and Exporters of Pre-charged 423730............................. Air-conditioning equipment (except
Equipment and Closed-Cell Foams. room units) merchant wholesalers.
333415............................. Air-conditioning equipment (except
motor vehicle) manufacturing.
423620............................. Air-conditioners, room, merchant
wholesalers.
[[Page 19804]]
443111............................. Household Appliance Stores.
326150............................. Polyurethane foam products
manufacturing.
335313............................. Circuit breakers, power,
manufacturing.
423610............................. Circuit breakers merchant
wholesalers.
Industrial Waste Landfills............ 562212............................. Solid waste landfills.
221320............................. Sewage treatment facilities.
322110............................. Pulp mills.
322121............................. Paper mills.
322122............................. Newsprint mills.
322130............................. Paperboard mills.
311611............................. Meat processing facilities.
311411............................. Frozen fruit, juice and vegetable
manufacturing facilities.
311421............................. Fruit and vegetable canning
facilities.
Industrial Wastewater Treatment....... 322110............................. Pulp mills.
322121............................. Paper mills.
322122............................. Newsprint mills.
322130............................. Paperboard mills.
311611............................. Meat processing facilities.
311411............................. Frozen fruit, juice, and vegetable
manufacturing facilities.
311421............................. Fruit and vegetable canning
facilities.
325193............................. Ethanol manufacturing facilities.
324110............................. Petroleum refineries.
Iron and Steel Production............. 331111............................. Integrated iron and steel mills,
steel companies, sinter plants,
blast furnaces, basic oxygen
process furnace shops.
Lead Production....................... 331419............................. Primary lead smelting and refining
facilities.
331492............................. Secondary lead smelting and
refining facilities.
Lime Production....................... 327410............................. Calcium oxide, calcium hydroxide,
dolomitic hydrates manufacturing
facilities.
Magnesium Production.................. 331419............................. Primary refiners of nonferrous
metals by electrolytic methods.
Municipal Solid Waste Landfills....... 562212............................. Solid waste landfills.
221320............................. Sewage treatment facilities.
Nitric Acid Production................ 325311............................. Nitric acid manufacturing
facilities.
Oil and Natural Gas Systems........... 486210............................. Pipeline transportation of natural
gas.
221210............................. Natural gas distribution
facilities.
325212............................. Synthetic rubber manufacturing
facilities.
Petrochemical Production.............. 32511.............................. Ethylene dichloride manufacturing
facilities.
325199............................. Acrylonitrile, ethylene oxide,
methanol manufacturing facilities.
325110............................. Ethylene manufacturing facilities.
325182............................. Carbon black manufacturing
facilities.
Petroleum Refineries.................. 324110............................. Petroleum refineries.
Phosphoric Acid Production............ 325312............................. Phosphoric acid manufacturing
facilities.
Petroleum and Natural Gas Systems..... 486210............................. Pipeline transportation of natural
gas.
221210............................. Natural gas distribution
facilities.
211................................ Extractors of crude petroleum and
natural gas.
211112............................. Natural gas liquid extraction
facilities.
Pulp and Paper Manufacturing.......... 322110............................. Pulp mills.
322121............................. Paper mills.
322130............................. Paperboard mills.
Soda Ash Manufacturing................ 325181............................. Alkalies and chlorine manufacturing
facilities.
Silicon Carbide Production............ 327910............................. Silicon carbide abrasives
manufacturing facilities.
Sulfur Hexafluoride (SF6) from 221121............................. Electric bulk power transmission
Electrical Equipment. and control facilities.
Titanium Dioxide Production........... 325188............................. Titanium dioxide manufacturing
facilities.
Underground Coal Mines................ 212113............................. Underground anthracite coal mining
operations.
212112............................. Underground bituminous coal mining
operations.
Zinc Production....................... 331419............................. Primary zinc refining facilities.
[[Page 19805]]
331492............................. Zinc dust reclaiming facilities,
recovering from scrap and/or
alloying purchased metals.
Suppliers of Industrial Greenhouse 325120............................. Industrial gas manufacturing
Gases. facilities.
Suppliers of Petroleum Products....... 324110............................. Petroleum refineries.
Suppliers of Natural Gas and Natural 221210............................. Natural gas distribution
Gas Liquids. facilities.
211112............................. Natural gas liquid extraction
facilities.
Suppliers of Carbon Dioxide (CO2)..... 325120............................. Industrial gas manufacturing
facilities.
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Table 1 of this preamble is not intended to be exhaustive, but
rather provides a guide for readers regarding facilities likely to be
affected by this action. Other types of facilities than those listed in
the table could also be subject to reporting requirements. To determine
whether you are affected by this action, you should carefully examine
the applicability criteria found in 40 CFR part 98, subpart A or the
relevant criteria in the sections related to suppliers and direct
emitters of GHGs. If you have questions regarding the applicability of
this action to a particular facility, consult the person listed in the
preceding FOR FURTHER GENERAL INFORMATION CONTACT Section.
Acronyms and Abbreviations. The following acronyms and
abbreviations are used in this document.
AF&PA American Forest & Paper Association
AR4 Fourth Assessment Report
BAMM best available monitoring methods
CAA Clean Air Act
CBI confidential business information
CBP U.S. Customs and Border Protection
CEMS continuous emissions monitoring system
CFC chlorofluorocarbon
CFR Code of Federal Regulations
CH4 methane
CO2 carbon dioxide
CO2e carbon dioxide equivalent
DOC degradable organic carbon
EAF electric arc furnace
e-GGRT Electronic Greenhouse Gas Reporting Tool
EF emission factor
EIA Energy Information Administration
EO Executive Order
EPA U.S. Environmental Protection Agency
[deg]F degrees Fahrenheit
FR Federal Register
GHG greenhouse gas
GHGRP Greenhouse Gas Reporting Program
GWP global warming potential
HFC hydrofluorocarbon
HHV high heat value
IPCC Intergovernmental Panel on Climate Change
ISBN International Standard Book Number
F-GHG fluorinated greenhouse gas
F-HTF fluorinated heat transfer fluid
kg kilograms
LDC Local Distribution Company
Mscf thousand standard cubic feet
MSW municipal solid waste
N2O nitrous oxide
NAICS North American Industry Classification System
NCASI National Council for Air and Stream Improvement
NGL natural gas liquid
OMB Office of Management and Budget
ORIS Office of the Regulatory Information System
PFC perfluorocarbon
QA/QC quality assurance/quality control
RFA Regulatory Flexibility Act
SAR Second Assessment Report
SF6 sulfur hexafluoride
SNAP Significant New Alternative Policy
TAR Third Assessment Report
UNFCCC United Nations Framework Convention on Climate Change
U.S. United States
UMRA Unfunded Mandates Reform Act of 1995
Organization of This Document. The following outline is provided to
aid in locating information in this preamble.
I. Background
A. How is this preamble organized?
B. Background on the Proposed Action
C. Legal Authority
II. Technical Corrections and Other Amendments
A. Subpart A--General Provisions
B. Subpart C--General Stationary Fuel Combustion Sources
C. Subpart H--Cement Production
D. Subpart K--Ferroalloy Production
E. Subpart L--Fluorinated Gas Production
F. Subpart N--Glass Production
G. Subpart O--HFC-22 Production and HFC-23 Destruction
H. Subpart P--Hydrogen Production
I. Subpart Q--Iron and Steel Production
J. Subpart X--Petrochemical Production
K. Subpart Y--Petroleum Refineries
L. Subpart Z--Phosphoric Acid Production
M. Subpart AA--Pulp and Paper Manufacturing
N. Subpart BB--Silicon Carbide Production
O. Subpart DD--Electrical Transmission and Distribution
Equipment Use
P. Subpart FF--Underground Coal Mines
Q. Subpart HH--Municipal Solid Waste Landfills
R. Subpart LL--Suppliers of Coal-based Liquid Fuels
S. Subpart MM--Suppliers of Petroleum Products
T. Subpart NN--Suppliers of Natural Gas and Natural Gas Liquids
U. Subpart PP--Suppliers of Carbon Dioxide
V. Subpart QQ--Importers and Exporters of Fluorinated Greenhouse
Gases Contained in Pre-Charged Equipment or Closed-Cell Foams
W. Subpart RR--Geologic Sequestration of Carbon Dioxide
X. Subpart SS--Electrical Equipment Manufacture or Refurbishment
Y. Subpart TT--Industrial Waste Landfills
Z. Subpart UU--Injection of Carbon Dioxide
AA. Other Technical Corrections
III. Schedule for the Proposed Amendments
A. When would the proposed amendments become effective?
B. Options Considered for Revision and Republication of
Emissions Estimates for Prior Year Reports
IV. Confidentiality Determinations
A. Overview and Background
B. Approach to Proposed Confidentiality Determinations for New
or Substantially Revised Data Elements
C. Proposed Confidentiality Determinations for Individual Data
Elements in Two Direct Emitter Data Categories and Two Supplier Data
Categories
D. Proposed New Inputs to Emission Equations
E. Request for Comments on Proposed Category Assignments and
Confidentiality Determinations
V. Impacts of the Proposed Rule
A. Impacts of the Proposed Amendments to Global Warming
Potentials
B. Additional Impacts of the Proposed Technical Corrections and
Other Amendments
VI. Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory Planning and Review and
Executive Order 13563: Improving Regulation and Regulatory Review
B. Paperwork Reduction Act
C. Regulatory Flexibility Act (RFA)
D. Unfunded Mandates Reform Act (UMRA)
E. Executive Order 13132: Federalism
[[Page 19806]]
F. Executive Order 13175: Consultation and Coordination with
Indian Tribal Governments
G. Executive Order 13045: Protection of Children from
Environmental Health Risks and Safety Risks
H. Executive Order 13211: Actions that Significantly Affect
Energy Supply, Distribution, or Use
I. National Technology Transfer and Advancement Act
J. Executive Order 12898: Federal Actions to Address
Environmental Justice in Minority Populations and Low-Income
Populations
I. Background
A. How is this preamble organized?
The first section of this preamble contains background information
regarding the origin of the proposed amendments. This section also
discusses EPA's legal authority under the Clean Air Act (CAA) to
promulgate (including subsequent amendments to) 40 CFR part 98 of the
Greenhouse Gas Reporting Rule (hereinafter referred to as ``Part 98'').
Section II of this preamble is organized by Part 98 subpart and
contains detailed information on the proposed revisions to the GHG
Reporting Rule and the rationale for the proposed amendments. Section
III of this preamble discusses the effective date of the proposed
revisions for new and existing reporters and the options EPA is
considering for revising and republishing emissions estimates for the
reporting years 2010, 2011, and 2012. Section IV of this preamble
discusses the proposed confidentiality determinations for new or
substantially revised (i.e., requiring additional or different data to
be reported) data reporting elements. Section V of this preamble
discusses the impacts of the proposed amendments, primarily for current
and new reporters of gases proposed to have revised or new global
warming potentials (GWPs) listed in Part 98. Finally, Section VI of
this preamble describes the statutory and executive order requirements
applicable to this action.
B. Background on the Proposed Action
Part 98 was published in the Federal Register on October 30, 2009
(74 FR 56260). Part 98 became effective on December 29, 2009, and
requires reporting of GHGs from certain facilities and suppliers.
Subsequent notices were published in 2010 promulgating the requirements
for subparts T, FF, II, and TT (75 FR 39736, July 12, 2010); subparts
I, L, DD, QQ, and SS (75 FR 74774, December 1, 2010); and subparts RR
and UU (75 FR 75060, December 1, 2010). A number of subparts have been
revised since promulgation (75 FR 79092, December 17, 2010; 76 FR
73866, November 29, 2011; 77 FR 10373, February 22, 2012; 77 FR 51477,
August 24, 2012). The EPA is proposing to further revise Part 98. This
proposed revision includes technical corrections, clarifying revisions,
and additional amendments to Part 98.
Changes proposed in this notice for certain source categories
include, among other things, clarifying the data reporting requirements
for certain facilities; correcting ambiguities or minor inconsistencies
in greenhouse gas monitoring, calculation, and reporting requirements;
amending monitoring and quality assurance methods to provide
flexibility for certain facilities; and making other corrections
identified as a result of working with the affected sources during rule
implementation and outreach. In conjunction with this action, we are
proposing confidentiality determinations for the new and substantially
revised (i.e., requiring additional or different data to be reported)
data elements under this proposed amendment.
In the first two years of implementation of Part 98, the EPA
responded to thousands of questions from reporters and engaged in a
stakeholder and public testing process to help improve development of
EPA's electronic reporting system. Through these extensive outreach
efforts, the EPA has improved our understanding of the technical
challenges and burden associated with implementation of Part 98
provisions. The proposed changes would improve the Greenhouse Gas
Reporting Program (GHGRP) by clarifying compliance obligations and
reducing confusion for reporters, improving the consistency of the data
collected, and ensuring that data collected through the GHGRP is
representative of industry and comparable to other inventories.
The EPA is also proposing amendments to Table A-1 to Subpart A,
General Provisions, of Part 98 to revise the values for the GWP of some
GHGs and adding some GHGs (with associated GWP values) that are not
currently included in the table.\1\ The newly added GWP values are from
the Intergovernmental Panel for Climate Change (IPCC) Fourth Assessment
Report \2\ (AR4) and EPA assessments of data supporting GWP estimates
for certain GHGs identified since promulgation. Data supporting the
proposed GWP estimates include information provided by chemical
manufacturers currently reporting under the GHGRP as well as published
literature. The EPA is proposing these changes to ensure comparability
of data collected in the GHGRP to the Inventory of U.S. Greenhouse Gas
Emissions and Sinks (hereinafter referred to as ``Inventory'') that the
EPA compiles annually to meet international commitments and to GHG
inventories prepared by other countries; to reflect improved scientific
understanding; and to promote consistency across the estimation methods
used in the rule.
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\1\ The GWP, a metric that incorporates both the heat-trapping
ability and atmospheric lifetime of each GHG, can be used to develop
comparable numbers by adjusting all GHGs relative to the GWP of
CO2. When quantities of the different GHGs are multiplied
by their GWPs, the different GHGs can be compared on a
CO2 basis. The GWP of CO2 is 1.0, and the GWP
of other GHGs are expressed relative to CO2. IPCC GWP
values are based on the effects of the greenhouse gases over a 100-
year time horizon. See 74 FR 16448, 53 (April 10, 2009).
\2\ IPCC Fourth Assessment Report (AR4), 2007. Climate Change
2007: The Physical Science Basis. Contribution of Working Group I to
the Fourth Assessment Report of the Intergovernmental Panel on
Climate Change.
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C. Legal Authority
The EPA is proposing these rule amendments under its existing CAA
authority provided in CAA section 114. As stated in the preamble to the
2009 final GHG reporting rule (74 FR 56260, October 30, 2009), CAA
section 114(a)(1) provides the EPA broad authority to require the
information proposed to be gathered by this rule because such data
would inform and are relevant to the EPA's carrying out a wide variety
of CAA provisions. See the preambles to the proposed (74 FR 16448,
April 10, 2009) and final Part 98 (74 FR 56260) for further
information.
In addition, the EPA is proposing confidentiality determinations
for certain new or substantially revised data elements required under
the proposed GHG Reporting Rule under its authorities provided in
sections 114, 301 and 307 of the CAA. As mentioned above, CAA section
114 provides the EPA authority to obtain the information in Part 98.
Section 114(c) requires that EPA make publicly available information
obtained under section 114 except for information (excluding emission
data) that qualify for confidential treatment. The Administrator has
determined that this action (proposed amendments and confidentiality
determinations) is subject to the provisions of section 307(d) of the
CAA.
II. Technical Corrections and Other Amendments
The EPA is proposing to revise Part 98 to introduce technical
corrections, clarifying revisions, and other amendments to Part 98 to
improve the
[[Page 19807]]
quality and consistency of the data collected by the EPA in response to
feedback received from stakeholders during program implementation. The
proposed amendments include the following types of changes:
Revising GWPs for GHGs defined in Table A-1 of subpart A
of Part 98 for consistency with the Inventory, and adding GWPs for
fluorinated greenhouse gases (F-GHGs) used by Part 98 facilities that
are not currently included in Table A-1 to reflect industry practices.
Changes to clarify the applicability of calculation
methods to certain sources at a facility.
Corrections to terms and definitions in certain equations
to provide clarity or better reflect actual operating conditions.
Changes to correct typographical errors or cross
references within and between subparts.
Amending monitoring and quality assurance methods to
provide flexibility for certain facilities.
Corrections to data reporting requirements so that they
more closely conform to the information used to perform emission
calculations.
Adding readily available data reporting requirements that
would allow the EPA to verify the data submitted and assess the
reasonableness of the data reported.
Other amendments or corrections related to certain issues
identified during rule implementation and outreach.
Sections II.A through II.AA of this preamble describe the more
substantive corrections, clarifying, and other amendments we are
proposing for each subpart. The proposed amendments discussed in this
preamble include: Changes that affect the applicability of a subpart,
changes that affect the applicability of a calculation method to a
specific source at a facility, changes or corrections to calculation
methods that substantially revise the calculation method or output of
the equation, revisions to data reporting requirements that would
substantively clarify the reported data element or introduce a new data
element, clarifications of general monitoring and quality assurance
requirements, and new terms and definitions. To reduce the length of
this preamble, we have summarized less substantive corrections for each
subpart in the memorandum, ``Table of 2013 Revisions to the Greenhouse
Gas Reporting Rule'' (hereafter referred to as the ``Table of
Revisions'') available in the docket for this rulemaking (EPA-HQ-OAR-
2012-0934). The proposed changes discussed in the Table of Revisions
are straightforward clarifications of requirements to better reflect
the EPA's intent, simple corrections to calculation terms or cross-
references that do not affect the output of calculations, harmonizing
changes within a subpart (such as changes to terminology), simple
editorial and minor error corrections, or removal of redundant text.
The Table of Revisions describes each proposed change within a subpart,
including those itemized in this preamble, and provides the current
rule text and the proposed correction. Where the proposed change is
listed only in the Table of Revisions, the rationale for the proposed
change is also listed there. You may comment on those proposed
technical corrections, clarifying and other amendments identified in
the Table of Revisions as well as any other part of this proposal.
A. Subpart A--General Provisions
1. Proposed Amendments to Subpart A--Global Warming Potentials
In today's action, we are proposing to revise Table A-1 of subpart
A of Part 98 (hereafter referred to as ``Table A-1'') by updating the
GWP values of certain compounds and adding certain F-GHGs and their
GWPs not previously included in Table A-1. These proposed changes
relate to facilities and suppliers under Part 98 reporting the
following greenhouse gases: methane (CH4), nitrous oxide
(N2O), sulfur hexafluoride (SF6),
hydrofluorocarbons (HFCs), perfluorocarbons (PFCs), and other F-
GHGs.\3\
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\3\ Fluorinated greenhouse gases, as defined in 40 CFR 98.6,
include sulfur hexafluoride, nitrogen trifluoride, and any
fluorocarbon except for controlled substances as defined at 40 CFR
part 82, subpart A and substances with vapor pressures of less than
1 mm of Hg absolute at 25 degrees C.
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The changes are being proposed for two reasons. First, we propose
to revise GWPs for GHGs currently in Table A-1 to ensure continued
consistency with the Inventory as the Inventory begins to use GWPs from
the IPCC Fourth Assessment Report. Second, we propose to add GWPs for
F-GHGs that are not currently included in Table A-1 but that are
emitted in significant quantities or for which newly available data or
literature supports the establishment of a GWP in Table A-1. The
background and general rationale for these proposed amendments are
discussed in Section II.A.1.a of this preamble. The proposed changes to
the GWPs currently in Table A-1 and the GWP determinations for new
proposed compounds in Table A-1 are discussed in Sections II.A.1.b and
II.A.1.c of this preamble. The schedule for the proposed amendments is
discussed in Section III.A of this preamble.
The EPA is also considering options for revising and republishing
emissions estimates for the reporting years 2010, 2011, and 2012 using
the revised GWPs in Table A-1. The EPA is seeking comment on these
options, which are discussed in Section III.B of this preamble. Because
reporters affected by the GHG reporting rule use the GWPs in Table A-1
to calculate annual GHG emissions (or GHGs supplied, as applicable),
and, for source categories with a carbon dioxide equivalent
(CO2e)-based threshold, to determine whether they are
required to report, the proposed new and revised GWPs could change the
number of reporters and the magnitude of emissions reported for some
source categories. If these amendments are finalized, some facilities
to which the rule did not previously apply may be required to report
based on increases in calculated GHG quantities that affect
applicability (see Section V of this preamble for additional
information). These impacts and the potential compliance costs of the
proposed amendments for affected subparts are discussed in Section V of
this preamble.
a. Background and General Rationale for GWP Revisions
U.S. GHG reporting programs and the IPCC Fourth Assessment Report.
As a party to the United Nations Framework Convention on Climate Change
(UNFCCC), the United States participates in ongoing negotiations with
the international community to promote global cooperation on climate
change. The UNFCCC treaty, ratified by the U.S. in 1992, sets an
overall framework for intergovernmental efforts to address the
challenges posed by climate change.\4\ As part of its commitment to the
UNFCCC, the U.S. submits the Inventory of U.S. Greenhouse Gas Emissions
and Sinks to the Secretariat of the UNFCCC as an annual reporting
requirement.\5\ The Inventory is a comprehensive assessment of U.S. GHG
emissions based on national-level data and is prepared by EPA's Office
of Air and
[[Page 19808]]
Radiation in coordination with other federal agencies. To ensure
consistency and comparability with national inventory data submitted by
other UNFCCC Parties, the Inventory submitted to the UNFCCC uses
internationally-accepted methods agreed upon by the Parties (including
the United States) to develop and characterize emission estimates.
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\4\ See United Nations Framework Convention on Climate Change,
1992. Available at: http://unfccc.int/resource/docs/convkp/conveng.pdf. For more information about the UNFCCC, please refer to:
http://www.unfccc.int.
\5\ See Articles 4 and 12 of the Convention on Climate Change.
Parties to the Convention, by ratifying, ``shall develop,
periodically update, publish and make available * * * national
inventories of anthropogenic emissions by sources and removals by
sinks of all greenhouse gases not controlled by the Montreal
Protocol, using comparable methodologies * * *.''
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As described in the preamble of the proposed GHG Reporting Rule (74
FR 16448, April 10, 2009), the GHGRP is intended to supplement and
complement existing U.S. government programs related to climate policy
and research, including the Inventory submitted to the UNFCCC. The
GHGRP provides data to develop and inform inventories and other U.S.
climate programs by advancing the understanding of emission processes
and monitoring methodologies for particular source categories or
sectors. Specifically, the GHGRP complements the Inventory and other
U.S. programs by providing data from individual facilities and
suppliers above certain thresholds.
Collected facility, unit, and process-level GHG data from the GHGRP
will provide or confirm the national statistics and emission estimates
presented in the Inventory, which are calculated using aggregated
national data. The EPA has received encouragement from stakeholders to
use GHG data from the GHGRP to complement the Inventory, such as from
EPA's stakeholder workshop for natural gas systems.\6\
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\6\ Stakeholder Workshop on the U.S. GHG Inventory for Natural
Gas Systems. September 13-14, 2012, Washington, DC. See http://www.epa.gov/climatechange/ghgemissions/Sept2012stakeholderworkshop.html.
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During the development of the GHG Reporting Rule, the EPA generally
proposed and finalized estimation methodologies and reporting metrics
that were based on recent scientific data and that were consistent with
the international reporting standards under the UNFCCC. This approach
allows the data collected under the GHGRP to be easily compared to the
data in the Inventory and to data from other national and international
programs. Specifically, the EPA generally promulgated GWP values
published in the IPCC Second Assessment Report (hereinafter referred to
as ``SAR GWP values'') to convert mass emissions (or supply) of each
GHG into a common unit of measure, CO2e, for final
reporting. At the time that Part 98 was finalized, in order to comply
with international reporting standards under the UNFCCC, official
emission estimates were to be reported by the United States and other
parties using SAR GWP values. Although the IPCC published its Fourth
Assessment Report (AR4) prior to publication of the final GHG reporting
rule (74 FR 56260), the UNFCCC continued to require the use of SAR GWP
values for reporting. For consistency and comparability of the data
collected between the GHGRP and the Inventory, the EPA adopted the SAR
GWP values in Table A-1 to subpart A of Part 98, with the exception of
GWPs for certain F-GHGs adopted from the IPCC AR4.\7\
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\7\ For certain F-GHGs that were not addressed by the SAR but
were included in Part 98 (e.g., NF3), the EPA promulgated
up-to-date GWPs from the IPCC AR4. (The one exception was
sevoflurane, whose GWP was based on a study by Langbein et al. as
explained in the February 6, 2009 Technical Support Document for
Industrial Gas Supply: Production, Transformation, and Destruction
of Fluorinated GHGs and N2O.) This approach was
consistent with the GWP values used for F-GHGs in the Inventory
prepared by the EPA as part of the U.S. commitment to the UNFCCC.
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The IPCC AR4 was published in 2007 and is among the most current
and comprehensive peer-reviewed assessments of climate change. The AR4
provides revised GWPs of several GHGs relative to the values provided
in previous assessment reports, following advances in scientific
knowledge on the radiative efficiencies and atmospheric lifetimes of
these GHGs and of CO2. Because the GWPs provided in the AR4
reflect an improved scientific understanding of the radiative effects
of these gases in the atmosphere, the values provided are more
appropriate for supporting the overall goal of the reporting program to
collect GHG data than the SAR GWP values currently included in Table A-
1. While we recognize that GWPs reflecting further scientific advances
may become available in the near future (e.g., the IPCC Fifth
Assessment Report, currently in development), it is not now EPA's
intent to revise the GWPs in Table A-1 each time new data are
published. Rather, we understand that it is also important for
stakeholders to have consistent, predictable requirements to avoid
confusion and additional burden. As discussed below, we are not
proposing to adopt GWP values from the Fifth Assessment Report because
it is our intent to have the GHGRP complement the requirements of the
Inventory.
On March 15, 2012, the UNFCCC published a decision, reached by
UNFCCC member parties, to require countries submitting an annual report
in 2015 and beyond to use GWP values from the IPCC AR4 (hereinafter
referred to as the ``AR4 GWP values'').\8\ Accordingly, the United
States has a commitment to submit the Inventory for 2015 and future
years using the revised AR4 GWP values. The Inventory for 2015 will
contain national level estimates of emissions for each year from 1990-
2013. In order to ensure that the GHGRP continues to complement and
inform the Inventory submitted to the UNFCCC and relies on recent
scientific data, we are proposing to revise the GWP values in Table A-1
of Part 98 to reflect the updated AR4 GWP values. The proposed changes
would keep the reporting metrics in Part 98 consistent with the updated
international reporting standards followed by the Inventory.
Additionally, the proposed changes would allow for improved
understanding of the radiative forcing from reported GHG emissions and
supply, based on GWP values that are more up-to-date relative to the
values currently provided in Table A-1. The proposed changes to Table
A-1 would also ensure that the data collected in the GHGRP can be
compared to other national and international inventories. These
proposed changes are in keeping with the Agency's decision to use
methods consistent with UNFCCC guidelines in the development of the
October 30, 2009 GHG Reporting Rule.
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\8\ Please refer to http://unfccc.int/. See Decision 15/CP.17,
Revision of the UNFCCC reporting guidelines on annual inventories
for Parties included in Annex I to the Convention. Parties of the
Convention ``* * * Decide[s] that, from 2015 until a further
decision by the Conference of the Parties, the global warming
potentials used by Parties to calculate the carbon dioxide
equivalence of anthropogenic emissions by sources and removals by
sinks of greenhouse gases shall be those listed in the column
entitled ``Global warming potential for given time horizon'' in
table 2.14 of the errata to the contribution of Working Group I to
the Fourth Assessment Report of the Intergovernmental Panel on
Climate Change * * *.''
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We recognize that some other EPA programs use the GWP values in
Table A-1 to determine applicability of the program to direct emitters
or suppliers above certain thresholds. For example, EPA's Greenhouse
Gas Tailoring Rule (75 FR 31514; June 3, 2010) cross-references Table
A-1 for calculating GHG emissions under the PSD and title V permitting
programs. See, e.g., 40 CFR 52.21(b)(49)(ii)(a). Because the permitting
applicability is based partly on CO2e emissions, which are
calculated using the GWP values codified in Table A-1, an amendment to
Table A-1 may affect program applicability for a source. As a result, a
source that is assessing applicability under the PSD or title V
permitting program should be aware of the
[[Page 19809]]
proposed changes to Table A-1 that may affect the CO2e
emissions of the source once the Table A-1 amendment is promulgated and
effective.\9\ To the extent that a Table A-1 amendment raises
permitting implementation questions or concerns, EPA's regional offices
and the Office of Air Quality Planning and Standards, which manage the
PSD and title V programs, will work with permitting authorities and
other stakeholders as necessary to provide guidance on their issues and
concerns. While we are seeking comments on specific GWP values proposed
in this action, we are not reopening for comment the decision made in
the Tailoring Rule, or any other rules or programs, to reference Table
A-1.
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\9\ This reliance of other EPA programs on Table A-1 promotes
implementation consistency and avoids having to revise the other
rules each time a GWP revision occurs. As noted in the Tailoring
Rule preamble, ``[a]ny changes to Table A-1 of the mandatory GHG
reporting rule regulatory text must go through an appropriate
regulatory process. In this manner, the values used for the
permitting programs will reflect the latest values adopted for usage
by EPA after a regulatory process and will be consistent with those
values used in the EPA's mandatory GHG reporting rule.'' (75 FR at
31522; June 3, 2010).
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Use of the AR4 GWPs is also in keeping with other EPA programs. For
example, the Agency decided to use these values in rules published
jointly with the Department of Transportation, National Highway Traffic
Safety Administration, the ``Light-Duty Vehicle Greenhouse Gas Emission
Standards and Corporate Average Fuel Economy Standards'' (75 FR 25324,
May 7, 2010).\10\
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\10\ While we are seeking comments on specific GWP values
proposed in this action, we are not reopening for comment the
decision made in the Light Duty Vehicle Rule, or any other rules or
programs, to use AR4 GWPs.
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Section II.A.1.b of this preamble lists the changes we are
proposing to incorporate as a result of the updated AR4 GWPs.
Identification of GWPs in the scientific literature.
During implementation of Part 98, the EPA has collected data on the
range and volume of F-GHGs emitted and supplied in the U.S. market by
various F-GHG producers, importers, exporters, and manufacturers using
F-GHGs in their production processes (e.g., electronics manufacturing,
magnesium production).\11\ The EPA reviewed available production and
usage data for existing and newly synthesized gases and assessed
available data substantiating the GWP calculation for gases for which a
GWP value was not included in Table A-1 in the October 30, 2009 final
rule. In this action, we are proposing to amend Table A-1 to add F-GHGs
emitted or supplied by reporters under subparts I (Electronics
Manufacturing), L (Fluorinated Gas Production), T (Magnesium
Production), OO (Industrial GHG Suppliers), and QQ (Importers and
Exporters of G-GHGs Contained in Pre-Charged Equipment and Closed-Cell
Foams). Section II.A.1.c of this preamble lists the changes we are
proposing to incorporate the additional F-GHGs into Table A-1.
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\11\ Fluorinated heat transfer fluids are defined as F-GHGs used
for temperature control, device testing, cleaning substrate surfaces
and other parts, and soldering in certain types of electronics
manufacturing production processes. Under subpart I, the lower vapor
pressure limit of 1 mm Hg in absolute at 25 [deg]C in the definition
of fluorinated greenhouse gas in 40 CFR 98.6 does not apply.
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The EPA is proposing to amend Table A-1 to subpart A of Part 98 to
add 26 F-GHGs for which we have identified a GWP based on an assessment
of recent scientific literature. Table A-1 to subpart A is a compendium
of GWP values of select GHGs that are required to be reported under one
or more subparts of Part 98, and where the EPA has identified the GWP
in the IPCC AR4 report or other sources. As acknowledged in the
preamble to the final Part 98 (74 FR 56260, October 30, 2009), Table A-
1 is not a complete listing of current or potential compounds, but
reflects only those GWPs for listed materials that had been
synthesized, their atmospheric properties investigated, and the results
published and reviewed prior to promulgation of the final rule.
Currently, some Part 98 source categories provide calculation
methodologies and reporting requirements for F-GHGs for which GWP
values were not available in the IPCC SAR, TAR, AR4, or other
scientific assessments at promulgation. As noted in the preamble to the
final Part 98 (74 FR 56260), it is the EPA's intent to periodically
update Table A-1 as GWPs are evaluated or re-evaluated by the
scientific community.
b. Proposed Revisions From the IPCC Fourth Assessment Report
The proposed amendments to Table A-1 would revise the GWPs for 23
GHGs to reflect the 100-year GWP values adopted by the UNFCCC and
published in the IPCC AR4. Table 2 of this preamble lists the GHGs
whose GWP values we are proposing to revise, along with the GWP values
currently listed in Table A-1 and the proposed revised GWP values from
the IPCC AR4.
Table 2--GHGs With Proposed Revised GWPs for Table A-1
----------------------------------------------------------------------------------------------------------------
Current global Proposed
Name CAS No. warming global warming
potential \a\ potential \b\
----------------------------------------------------------------------------------------------------------------
Methane......................................................... 74-82-8 21 25
Nitrous oxide................................................... 10024-97-2 310 298
HFC-23.......................................................... 75-46-7 11,700 14,800
HFC-32.......................................................... 75-10-5 650 675
HFC-41.......................................................... 593-53-3 150 92
HFC-125......................................................... 354-33-6 2,800 3,500
HFC-134......................................................... 359-35-3 1,000 1,100
HFC-134a........................................................ 811-97-2 1,300 1,430
HFC-143......................................................... 430-66-0 300 353
HFC-143a........................................................ 420-46-2 3,800 4,470
HFC-152a........................................................ 75-37-6 140 124
HFC-227ea....................................................... 431-89-0 2,900 3,220
HFC-236fa....................................................... 690-39-1 6,300 9,810
HFC-245ca....................................................... 679-86-7 560 693
HFC-43-10mee.................................................... 138495-42-8 1,300 1,640
Sulfur hexafluoride............................................. 2551-62-4 23,900 22,800
PFC-14 (Perfluoromethane)....................................... 75-73-0 6,500 7,390
PFC-116 (Perfluoroethane)....................................... 76-16-4 9,200 12,200
PFC-218 (Perfluoropropane)...................................... 76-19-7 7,000 8,830
[[Page 19810]]
PFC-3-1-10 (Perfluorobutane).................................... 355-25-9 7,000 8,860
Perfluorocyclobutane............................................ 115-25-3 8,700 10,300
PFC-4-1-12 (Perfluoropentane)................................... 678-26-2 7,500 9,160
PFC-5-1-14 (Perfluorohexane).................................... 355-42-0 7,400 9,300
----------------------------------------------------------------------------------------------------------------
\a\ From Table A-1 to subpart A of the October 30, 2009 GHG Reporting Rule.
\b\ From Table 2.14 of the errata to Working Group 1 of the IPCC AR4.
We are proposing to adopt only GWP values based on a 100-year time
horizon, although other time horizons are available in the IPCC AR4
(e.g., 20-year or 500-year GWPs). As acknowledged in the April 10, 2009
proposed GHG reporting rule (74 FR 16448), the parties to the UNFCCC
agreed to use GWPs based upon a 100-year time horizon. Therefore, 100-
year GWPs are used as the metric in the Inventory. Because the proposed
changes are intended to make the GHGRP reporting methods more
consistent with the Inventory, we are not considering the use of GWPs
based on other time horizons.
As noted above, Table A-1 already includes AR4 GWPs for chemicals
for which GWPs were not presented in the SAR (e.g., fluorinated
ethers); the EPA is therefore proposing to retain the current GWPs for
these chemicals (and for sevoflurane, which has not been included in
any IPCC assessment but already is included in Table A-1). A complete
listing of the current GWPs in Table A-1 to subpart A and the AR4 GWP
values may be found in the memorandum, ``Assessment of Emissions and
Cost Impacts of 2013 Revisions to the Greenhouse Gas Reporting Rule''
(hereafter referred to as ``Impacts Analysis'') (see Docket ID No. EPA-
HQ-OAR-2012-0934).
For one set of chemicals, fluorinated ethers and alcohols, the EPA
is seeking comment on adopting GWPs from an international scientific
assessment published more recently than AR4, the WMO (World
Meteorological Organization) Scientific Assessment of Ozone Depletion:
2010 (Global Ozone Research and Monitoring Project-Report No. 52, 516
pp., Geneva, Switzerland, 2011). Like the IPCC Assessment Reports, the
WMO Scientific Assessments include regularly updated international
reviews of the scientific findings on the lifetimes and impacts of
trace gases in the atmosphere. While the primary focus of the WMO
Scientific Assessments is depletion of stratospheric ozone, they have
also included estimated GWPs for a number of fluorocarbons that do not
deplete stratospheric ozone (many of which are substitutes for ozone-
depleting substances) since 1989.
The current Table A-1 includes AR4 GWPs for several fluorinated
ethers and alcohols, including several hydrofluoroethers (HFEs), which
could be updated through the WMO Scientific Assessments. These
fluorinated ethers and alcohols are not required to be included in
national GHG inventories reported under the UNFCCC. In general, the
compounds required to be reported under the GHGRP go beyond the minimum
reporting requirements of the UNFCCC (e.g., NF3 or
fluorinated heat transfer fluids). These compounds were included in
Part 98 because they are long-lived in the atmosphere, have high GWPs,
and, in many cases, are used in expanding industries or as substitutes
for HFCs (see 74 FR 16464, April 10, 2009). Thus, adopting GWPs for
these compounds from an international assessment that is more recent
than the AR4 would not conflict with UNFCCC reporting.
The 2010 WMO Scientific Assessment includes significant updates to
the GWPs for several HFEs in commerce, reflecting improved
understanding of the atmospheric lifetimes and radiative efficiencies
of these chemicals. In a number of cases, estimated 100-year GWPs for
HFEs have approximately doubled; in one, (for HFE-338mmz1), the
estimated 100-year GWP rose by over a factor of six, from 380 to 2570.
(The changes to the estimated GWPs of other fluorinated GHGs, such as
the HFCs and PFCs, were far smaller.) To ensure consistency between the
GHGRP and UNFCCC reporting, the EPA is not proposing to adopt GWPs from
the 2010 WMO Scientific Assessment for chemicals other than fluorinated
ethers and alcohols. However, the EPA requests comment on adopting GWPs
from the 2010 WMO Scientific Assessment for a subset of chemicals,
fluorinated ethers and alcohols, that are not reported under the
Inventory.
We are not proposing to include GWPs for ozone-depleting substances
controlled by the Montreal Protocol \12\ and by Title VI of the CAA
(e.g., chlorofluorocarbons, hydrochlorofluorocarbons, and halons) in
Table A-1, although the IPCC AR4 includes updated GWPs for them. These
controlled substances are specifically excluded from the definition of
GHG, F-GHG, and F-HTF under Part 98 (and thus not required to be
reported under Part 98), as these substances are already effectively
reported under 40 CFR part 82. Furthermore, the reduction of these
substances is controlled under the Montreal Protocol. The UNFCCC does
not cover these substances or require reporting of these substances by
UNFCCC parties,\13\ so collecting data on these substances is
unnecessary to complement or supplement the Inventory.
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\12\ The Montreal Protocol on Substances that Deplete the Ozone
Layer is an international treaty that controls and phases out
various ozone-depleting substances including chlorofluorocarbons,
hydrochlorofluorocarbons and halons. These compounds are regulated
in the U.S. under Title VI of the CAA. The UNFCCC does not cover
these substances, and instead defers their treatment to the Montreal
Protocol.
\13\ Refer to: http://www.unfccc.int. See Article 4 of the
Convention on Climate Change.
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c. Proposed Additional F-GHGs and GWPs for Table A-1
We are proposing to include 26 new F-GHGs in Table A-1 of subpart A
for which the EPA has identified scientific assessments of the GWPs.
These F-GHGs were not included in AR4 for a variety of reasons.\14\ As
discussed in Section II.A.1.a of this preamble, the F-GHGs we are
proposing to include in Table A-1 are emitted or supplied by reporters
under subparts I, L, T, OO, and QQ. Including GWP values in Table A-1
for these compounds would ensure that their atmospheric impacts are
accurately reflected in annual reports, threshold determinations, or
other calculations, as appropriate for each subpart in Part 98. In
general, those F-
[[Page 19811]]
GHGs whose GWPs are currently not listed in Table A-1 are not currently
included in threshold calculations for applicability or in the
CO2e totals reported by facilities and suppliers \15\
(although they are currently reported in metric tons of substance
emitted or supplied (40 CFR 98.3(c)(4))). Where their GWPs are low,
these compounds may have little effect on facility CO2e
totals. However, where their GWPs are high, they may have a large
effect on those totals.
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\14\ In some cases, the F-GHGs had not been developed or had not
become commercially important in time for inclusion in AR4; in
others, the F-GHGs were known to have short atmospheric lifetimes
and/or low GWPs.
\15\ The one exception to this is F-GHGs reported under subpart
L. Under a final rule published on August 24, 2012 (77 FR 51477),
fluorinated gas producers are required for RY 2011 and RY 2012 to
report total annual emissions in CO2e and to use either
default or best-estimate GWPs for fluorinated GHGs that do not have
GWPs listed in Table A-1.
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In some cases, the proposed additions to Table A-1 would help to
ensure that all Part 98 facilities emitting or supplying the identified
F-GHGs would use consistent GWPs to calculate emissions of
CO2e. For example, GWPs are used in 40 CFR 98.123(c)(1), a
provision of subpart L of Part 98 (Fluorinated Gas Production), to
determine the emission estimation method for continuous process
vents.\16\ Under 40 CFR 98.123(c)(1)(v), subpart L reporters must use
the GWPs in Table A-1 to convert F-GHG emissions to CO2e for
a preliminary estimate of emissions. For F-GHGs whose GWPs are not
listed in Table A-1, subpart L reporters must use a default GWP of
2,000 unless they submit a request to use provisional GWPs for those F-
GHGs following the requirements of 40 CFR 98.123(c)(1)(vi) and the EPA
approves the request. Provisional GWPs may be used only in the
calculations in 40 CFR 98.123(c)(1) and only by the facilities for
which they have been approved.\17\ Therefore, although the EPA may have
reviewed and substantiated provisional GWP values for select F-GHGs for
certain producers to use in determining the emission estimation method
for continuous process vents under subpart L, the provisional GWPs may
not be used by other Part 98 facilities. Including the proposed F-GHGs
in Table A-1 would reduce burden for facilities that may otherwise be
required to perform stack testing based on the default GWP (e.g., if
the default GWP overstates the radiative efficiency of the F-GHG).
Additionally, including these F-GHGs in Table A-1 would provide more
accurate reporting than the use of the default GWPs under subpart L.
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\16\ This is part of the provision of subpart L that allows
facilities to request to use provisional GWPs to calculate a
preliminary estimate of emissions from each process vent. If the
preliminary estimate indicates that a vent emits 10,000 metric tons
CO2e or more, the subpart L reporter is required to use
stack testing to establish an emission factor for the continuous
process vent. If the preliminary estimate indicates that the vent
emits less than 10,000 metric tons CO2e, the subpart L
reporter may use engineering calculations or assessments to develop
an emission calculation factor.
\17\ For reporting years 2011 and 2012, subpart L reporters may
use a best estimate of the GWP meeting the data requirements for
provisional GWPs in 40 CFR 98.123(c)(1)(vi)(A)(3) as part of their
facility-wide reported emissions.
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The proposed F-GHGs include F-GHGs for which the EPA has previously
reviewed scientific assessments from requests for provisional GWPs, F-
GHGs submitted by a fluorinated GHG producer with suggested GWPs and
supporting data and analysis on August 21, 2012, and F-GHGs for which
evaluations of the GWPs were performed by the EPA (e.g., as part of
evaluations associated with EPA's Significant New Alternative Policy
(SNAP) program), or published in peer-reviewed scientific journals.
\18\ Specifically, the compounds we are proposing to add to Table A-1
of subpart A include:
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\18\ The SNAP program is EPA's program to evaluate substitutes
for the ozone-depleting substances that are being phased out under
the stratospheric ozone protection provisions of the Clean Air Act
(as implemented in 40 CFR part 82). As part of EPA's assessment of a
substitute's overall risk to human health and the environment, the
EPA reviews scientific assessments of the GWP and considers this,
among other criteria, in evaluating a substitute.
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Seven compounds for which the EPA has approved provisional
GWPs for purposes of the calculations in 40 CFR 98.123(c)(1). The EPA
reviewed scientific assessments of the GWPs for these F-GHGs as
provided with provisional GWP requests received from Honeywell
International (``Honeywell'') and DuPont de Nemours, Inc. (``DuPont'')
and published in the February 3, 2012 Notice of Data Availability (77
FR 5514). The EPA approved provisional GWPs for one F-GHG for
Honeywell, and for six F-GHGs for DuPont. The EPA finalized its
determinations for these compounds on February 24, 2012 (see Docket ID
No. EPA-HQ-OAR-2009-0927-0273). Based on EPA's review of the GWP
estimation methods for these compounds, we are proposing to amend Table
A-1 to include these seven gases.
Four compounds submitted with provisional GWP requests for
which the EPA did not approve provisional GWPs (including three F-GHGs
for DuPont, and one F-GHG for Honeywell). The companies submitted
scientific data supporting the GWPs of these four compounds, which was
made available in the February 3, 2012 Notice of Data Availability (77
FR 5514). (see Docket ID No. EPA-HQ-OAR-2009-0927-0256 for further
discussion of the scientific assessments reviewed). The EPA did
evaluate the GWPs of these F-GHGs, but not for the purposes of the
calculations in 40 CFR 98.123(c) because the calculated emission rates
of these chemicals, when using the default GWP, did not exceed the
10,000 metric tons CO2e threshold and did not meet the
conditions of 40 CFR 98.123(c)(1)(v). The fact that the EPA did not
approve the GWPs for purposes of the calculations in 40 CFR
98.123(c)(1) was not due to disagreement with the companies' suggested
GWPs. Therefore, the EPA is also proposing to amend Table A-1 to
include these four gases.
Ten F-GHGs submitted by DuPont on August 21, 2012, with
supporting data and analysis (see Table 3 of this preamble). We are
proposing to include the ten compounds in Table A-1. For each compound,
DuPont included peer-reviewed scientific data supporting the suggested
GWP.
Five F-GHGs which were identified from the EPA's review of
industrial gases produced for or used in the electronics manufacturing,
fluorinated gas production, magnesium production, electrical equipment
manufacture or refurbishment, and industrial gas supplier source
categories and for which scientific assessments or other documentation
of the GWPs were identified through the EPA's SNAP Program or peer-
reviewed literature. These compounds are identified under the common
names FK-5-1-12 (NovecTM 612), FK-6-1-12 (NovecTM
774), trans-1-chloro-3,3,3-trifluoroprop-1-ene, PFC-6-1-12, and PFC-7-
1-18.
Determination of proposed GWPs. To determine the proposed GWPs for
each compound, the EPA reviewed the scientific literature for each
compound and evaluated the accuracy of the estimation methods and
assumptions used to derive the GWP.\19\ A detailed description of the
EPA's analysis may be found in the memorandum, ``GWP
[[Page 19812]]
Determinations for Proposed Additional F-GHGs for Table A-1'', Docket
ID No EPA-HQ-OAR-2012-0934. The proposed GWP for each of the 26
compounds is included in Table 3 of this preamble; Table 3 also
includes how each compound was identified for inclusion in Table A-1 of
subpart A.
---------------------------------------------------------------------------
\19\ The key component of the GWP calculation is the time-
integrated radiative forcing of a one-kg emission of the compound
over a 100-year time horizon. The accuracy of the radiative forcing
calculation depends on the accuracies of the infrared absorption
spectrum and the atmospheric lifetime of the compound. The lifetime
is affected by the compound's reaction rates through reaction with
atmospheric oxidants (e.g., ozone or hydroxyl radicals) or through
photolysis (destruction by light). These rates, as well as the
radiative efficiency of the compound, depend on the distribution of
the compound in the atmosphere with altitude, latitude and
longitude. The factors affecting GWPs are discussed in more detail
in Supporting Analysis for Mandatory Reporting Of Greenhouse Gases:
Notice Of Preliminary Determinations Regarding Requests to Use
Provisional Global Warming Potentials Under the Fluorinated Gas
Production Category of the Greenhouse Gas Reporting Rule (January
23, 2011), which is available in Docket EPA-HQ-OAR-2012-0934.
Table 3--Proposed F-GHGs With GWPs for Table A-1
----------------------------------------------------------------------------------------------------------------
Proposed Origin of compound
Chemical designation or common name CAS No. Chemical formula GWP and GWP assessments
----------------------------------------------------------------------------------------------------------------
HFC-1234ze(E)...................... 29118-24-9 C3H2F4 6 Approved as
provisional GWP for
Honeywell
International (see
EPA-HQ-OAR-2009-0927
-0273, February 24,
2012).
hexafluoropropylene (HFP).......... 116-15-4 C3F6 0.25 Approved as
provisional GWP for
DuPont de Nemours
(see EPA-HQ-OAR-2009-
0927-0273, February
24, 2012).
perfluoromethyl vinyl ether (PMVE). 1187-93-5 CF(CF3)OCF3 3 Approved as
provisional GWP for
DuPont de Nemours
(see EPA-HQ-OAR-2009-
0927-0273, February
24, 2012).
tetrafluoroethylene (TFE).......... 116-14-3 C2F4 0.02 Approved as
provisional GWP for
DuPont de Nemours
(see EPA-HQ-OAR-2009-
0927-0273, February
24, 2012).
trifluoro propene (TFP)............ 677-21-4 C3H3F3 3 Approved as
provisional GWP for
DuPont de Nemours
(see EPA-HQ-OAR-2009-
0927-0273, February
24, 2012).
vinyl fluoride (VF)................ 75-02-5 C2H3F 0.7 Approved as
provisional GWP for
DuPont de Nemours
(see EPA-HQ-OAR-2009-
0927-0273, February
24, 2012).
vinylidine Fluoride (VF2).......... 75-38-7 C2H2F2 0.9 Approved as
provisional GWP for
DuPont de Nemours
(see EPA-HQ-OAR-2009-
0927-0273, February
24, 2012).
carbonyl fluoride.................. 353-50-4 COF2 2 Submitted with
provisional GWP
request for DuPont
de Nemours, no
provisional GWP
approved (see EPA-HQ-
OAR-2009-0927-0273,
February 24, 2012).
perfluoropropyl vinyl ether........ 1623-05-8 C5F10O 3 Submitted with
provisional GWP
request for DuPont
de Nemours, no
provisional GWP
approved (see EPA-HQ-
OAR-2009-0927-0273,
February 24, 2012).
perfluoroethyl vinyl ether......... 10493-43-3 C4F8O 3 Submitted with
provisional GWP
request for DuPont
de Nemours, no
provisional GWP
approved (see EPA-HQ-
OAR-2009-0927-0273,
February 24, 2012).
HFC-1234yf......................... 754-12-1 C3H2F4 4 Submitted with
provisional GWP
request for
Honeywell
International, no
provisional GWP
approved (see EPA-HQ-
OAR-2009-0927-0273,
February 24, 2012).
perfluorethyl iodide (2-I)......... 354-64-3 C2F5I 3 Submitted in August
2012 by DuPont de
Nemours.
perfluorbutyl iodide (PFBI, 42-I).. 423-39-2 C4F9I 3 Submitted in August
2012 by DuPont de
Nemours.
perfluorhexyl iodide (6-I)......... 355-43-1 CF3CF2CF2CF2CF2CF2IC6F1 2 Submitted in August
3I 2012 by DuPont de
Nemours.
perfluoroctyl iodide (8-I)......... 507-63-1 C8F17I 2 Submitted in August
2012 by DuPont de
Nemours.
1,1,1,2,2-pentafluoro-4-iodo butane 40723-80-6 C4H4F5I 2 Submitted in August
(22-I). 2012 by DuPont de
Nemours.
1,1,1,2,2,3,3,4,4-nonafluoro-6-iodo 2043-55-2 C6H4F9I 2 Submitted in August
hexane (42-I). 2012 by DuPont de
Nemours.
perfluorobutyl ethene (42-U)....... 19430-93-4 C6H3F9 2 Submitted in August
2012 by DuPont de
Nemours
perfluorohexyl ethene (62-U)....... 25291-17-2 C8H3F13 1 Submitted in August
2012 by DuPont de
Nemours.
perfluorooctyl ethene (82-U);...... 21652-58-4 C10H3F17 1 Submitted in August
2012 by DuPont de
Nemours.
[[Page 19813]]
1H,1H, 2H,2H-perfluorohexan-1-ol 2043-47-2 C6H5F9O 5 Submitted in August
(42-AL). 2012 by DuPont de
Nemours.
FK-5-1-12; NovecTM 612; FK-5-1- 756-13-8 CF3CF2C(O)CF(CF3)2 1.8 Published under EPA's
12myy2; n-Perfluorooctane; SNAP Program (40 CFR
Octanedecafluorooctane. part 82) and
identified in
manufacturer's
literature.
FK-6-1-12/NovecTM 774, C7 813-44-5 and C7F14O Chemical Blend 1 Published under EPA's
Fluoroketone. 813-45-6 SNAP Program (40 CFR
part 82).
trans-1-chloro-3,3,3-trifluoroprop- 2730-43-0 C3H2ClF3 7 Published under EPA's
1-ene. SNAP Program (40 CFR
part 82) and
identified in peer
reviewed literature.
PFC-6-1-16; Hexadecafluoroheptane.. 335-57-9 C7F16 7930 Identified in peer
reviewed literature.
PFC-7-1-18; Octadecafluorooctane... 307-34-6 C8F18 8340 Identified in peer
reviewed literature.
----------------------------------------------------------------------------------------------------------------
For the first 11 compounds in Table 3 (seven with approved
provisional GWPs and the four without approved provisional GWPs), the
EPA determined that the methods used to estimate the GWPs were likely
to overestimate the GWPs by an order of magnitude or more (see Docket
ID No. EPA-HQ-OAR-2009-0927-0256). These compounds are all relatively
short-lived, and the analyses to determine the GWP for these compounds
used the simplifying assumptions that the compounds are well-mixed in
the atmosphere. In general, the assumption that short-lived compounds
are well-mixed overestimates the radiative forcing of these gases and
may affect estimates of the atmospheric lifetime. Because of this
simplifying assumption, the proposed GWPs are likely to be
overestimates. However, the EPA has determined that the proposed GWPs
for these short-lived gases represent the most current, peer-reviewed,
scientific knowledge of the radiative properties and lifetimes of these
gases. For subpart L reporters, the proposed GWPs would provide a more
accurate calculation of CO2e emissions than the default GWPs
required under 40 CFR 98.123(a). Furthermore, because the GWP of each
of these 11 F-GHGs is very low (i.e., between 0.02 and 6, as shown in
Table 3 of this preamble), the EPA has determined that the proposed
GWPs would not significantly overestimate source category emissions or
supply and are acceptable for the purposes of calculating emissions
under Part 98.
For the ten F-GHGs submitted by DuPont on August 21, 2012, the
radiative efficiency of each compound is derived using a constant
mixing ratio of the compounds in the troposphere (i.e., the methods
assume that the compounds are well-mixed). These compounds are all
anticipated to be short-lived in the atmosphere. Therefore, the
constant mixing ratio likely overestimates the share of these compounds
that reside higher in the atmosphere and consequently overestimates the
radiative efficiency (and GWP). For four of the 10 compounds, the
approach used to calculate the atmospheric lifetimes likely
underestimates the lifetimes of these compounds.\20\ However, the
radiative efficiency calculation is likely to outweigh the
underestimated lifetimes. The EPA reviewed recent research that
suggests the approach used to determine the radiative efficiency for
these compounds can result in overestimates of the 100-year GWP of 49
to 233 percent (see ``GWP Determinations for Proposed Additional F-GHGs
for Table A-1,'' Docket ID No EPA-HQ-OAR-2012-0934 for additional
information on this analysis). The available estimates for these GWPs
are likely upper bounds, because these are short-lived, low-GWP gases.
We are proposing to include the GWPs for these ten F-GHGs in Table A-1
of subpart A. Because the GWP of each F-GHG is very low (i.e., between
1 and 5, as shown in Table 3), the EPA has determined that the proposed
GWPs would not significantly overestimate source category emissions or
supply and are acceptable for the purposes of calculating emissions
under Part 98.
---------------------------------------------------------------------------
\20\ The methods used assumed that these gases were well-mixed;
this underestimates the concentration of O3 and
overestimates the concentration of OH to which the compound is
actually exposed. The overestimate of the OH concentration has a
greater effect on the reaction rate and estimated lifetime of the
compound.
---------------------------------------------------------------------------
For the five F-GHGs identified through scientific assessments
published through EPA's SNAP program or in peer-reviewed literature,
the EPA evaluated the estimation methods used to determine the GWP for
each compound. The EPA's determination for each compound (identified by
common name) and the proposed GWPs are as follows:
FK-5-1-12 (NovecTM 612, NovecTM
1230). FK-5-1-12 is a fluorinated ketone; it is known under the trade
name NovecTM 612 when used as a magnesium cover gas and as
NovecTM 1230 when used as a fire suppression agent. Product
information provided by the manufacturer provides a GWP estimate of 1
for a 100-year integration using IPCC 2007 calculation methods.\21\ An
analysis of the GWP of FK-5-1-12 was also performed through EPA's SNAP
Program.\22\ The SNAP analysis considered two scientific reports that
provided estimates of atmospheric lifetime and radiative efficiency,
and determined that the total GWP of FK-5-1-12 (integrated over a 100-
year time horizon and calculated using the IPCC approach) would likely
have a value between 0.6 and 1.8. The total GWP comprises a direct
value of less than 1 but greater than zero plus an indirect GWP of 0.56
to 0.84, based on 4 to 6 carbons available for conversion to
CO2. The EPA is conservatively proposing a GWP of 1.8. For
the upper-bound value, the methods used to evaluate the radiative
efficiency for FK-5-1-12 assumed a constant mixing ratio for the
compound, which likely overestimated the radiative efficiency and the
GWP. Because the proposed GWP of the compound is so low, we do not
anticipate that the proposed value would result in substantial over-
reporting for the magnesium production source category.
---------------------------------------------------------------------------
\21\ 3M Company. ``3MTM NovecTM 1230 Fire
Protection Fluid.'' 2009. Available online at: http://multimedia.3m.com/mws/mediawebserver?mwsId=66666UF6EVsSyXTtlXfyn8TEEVtQEVs6EVs6EVs6E666666-&fn=prodinfo_novec1230.pdf.
\22\ See Docket ID No. EPA-HQ-OAR-2012-0934.
---------------------------------------------------------------------------
FK-6-1-12 (NovecTM 774, C7 Fluoroketone). The
compound FK-6-1-12 (also produced under the trade name
NovecTM 774), is a blend of two isomers: 3-
pentanone,1,1,1,2,4,5,5,5-octafluoro-2,4-bis(trifluoromethyl) and 3-
[[Page 19814]]
hexanone,1,1,1,2,4,4,5,5,6,6,6-undecafluoro-2-(trifluoromethyl). The
GWP of FK-6-1-12 was previously evaluated and published under EPA's
SNAP Program.\23\ The SNAP analysis provided a 100-year integrated GWP
of approximately 1, therefore, we are proposing to include a GWP value
of 1 in Table A-1. The compound also has a chemical structure similar
to that of FK-5-1-12, therefore, we anticipate a similar lifetime and
GWP for these compounds.
---------------------------------------------------------------------------
\23\ See ``Protection of Stratospheric Ozone: Determination 27
for Significant New Alternatives Policy Program,'' Docket ID No.
EPA-HQ-OAR-2012-0934.
---------------------------------------------------------------------------
trans-1-chloro-3,3,3-trifluoroprop-1-ene. The compound
trans-1-chloro-3,3,3-trifluoroprop-1-ene (trade name Solstice\TM\
1233zd(E)) is a polyurethane foam blowing agent useful in applications
such as thermal insulation in appliances and residential and commercial
buildings. An analysis of the GWP of trans-1-chloro-3,3,3-
trifluoroprop-1-ene was previously performed through EPA's SNAP
Program.\24\ As part of the SNAP analysis, the EPA considered two
studies, Anderson et al. (2008) \25\ and Wang et al. (2011),\26\ and
established a GWP of between 4.7 and 7 and an atmospheric lifetime of
approximately 26 to 31 days. In its evaluation, the EPA has given
weight to the peer-reviewed analysis by Anderson et al. (2008), which
calculates a GWP of 7. We are also considering research by Wang et al.
(In draft) \27\ which calculates a lifetime of 30.5 days and estimates
a GWP of 4.7. The model used by Wang et al. accounts for the shorter
lifetime and reduced mixing of the trans-1-chloro-3,3,3-trifluoroprop-
1-ene compound, and may provide a more accurate estimate of the GWP.
Although the latter two of the studies cited (from the same author)
give a GWP of 4.7, the EPA has determined that it is more appropriate
to use the GWP from the first study, as it comes from a peer-reviewed
journal article. Also, consistent with the reasoning for choosing
possibly upper-bound GWPs for other chemicals in Table 3 of this
preamble, the EPA has concluded that using the GWP of 7 rather than 4.7
would not significantly overestimate source category emissions or
supply and is acceptable for the purposes of calculating emissions
under Part 98.
---------------------------------------------------------------------------
\24\ See ``Protection of Stratospheric Ozone: Determination 27
for Significant New Alternatives Policy Program,'' Docket ID No.
EPA-HQ-OAR-2012-0934.
\25\ Andersen, M.P.S., E.J.K. Nilsson, O.J. Nielsen, M.S.
Johnson, M.D. Hurley, and T.J. Wallington. 2008. Atmospheric
chemistry of trans-CF3CH CHCl: Kinetics of the gas-phase reactions
with Cl atoms, OH radicals, and O3. J. Photochem. Photobiol. A:
Chemistry 199: 92-97.
\26\ Wang D., Olsen S., Wuebbles D. 2011. ``Preliminary Report:
Analyses of tCFP's Potential Impact on Atmospheric Ozone.''
Department of Atmospheric Sciences. University of Illinois, Urbana,
IL. September 26, 2011.
\27\ Wang, D., Wuebbles, D.J., Patten, K.O., and Olsen, S.C. In
draft. Climate advantages of proposed short-lived compounds as
replacements for longer-lived HCFCs and HFCs. Department of
Atmospheric Sciences, University of Illinois at Urbana-Champaign,
Urbana, Illinois. Draft report, undated.
---------------------------------------------------------------------------
PFC 6-1-16 and PFC 7-1-18. The perfluorocarbons (PFCs)
C7F16 and C8F18 are used as
heat transfer fluids and in vapor phase reflow soldering in the
electronics manufacturing industry. There are no previous estimates of
the GWPs for these gases. Ivy et al. (2012) \28\ have recently provided
emission estimates and measured infrared spectra of these PFCs to
estimate the GWPs. These compounds have an estimated atmospheric
lifetime of 3,000 years and are expected to be well-mixed in the
atmosphere. Because the expected lifetimes of these PFCs are much
longer than the 100-year time horizon used to calculate the GWP, they
are relatively insensitive to the estimated lifetime. Furthermore, the
methods and assumptions used by Ivy et al. (2012) are generally
considered reliable for long-lived gases. Therefore, we are proposing
the GWPs for these two compounds as presented by Ivy et al., as listed
in Table 3 of this preamble.
---------------------------------------------------------------------------
\28\ Ivy, D.J., M. Rigby, M. Baasandorj, J. B. Burkholder, and
R. G. Prinn. 2012. Global emission estimates and radiative impact of
C4F10, C5F12, C6F14, C7F16 and C8F18. Atmos. Chem. Phys., 12: 7635-
7645. DOI:10.5194/acp-12-7635-2012.
---------------------------------------------------------------------------
A complete analysis of each of these compounds and the proposed
GWPs are included in the memorandum, ``GWP Determinations for Proposed
Additional F-GHGs for Table A-1,'' Docket ID No. EPA-HQ-OAR-2012-0934.
Request for additional information. The GWPs we are proposing in
Table A-1 are based on the data available to the EPA at the time of
this proposed rulemaking. We specifically solicit comment on the
proposed GWPs for the 26 compounds we are proposing in Table A-1,
including submittal of additional data or analyses that may support
more accurate estimates of the GWP or that support the GWP estimation
methods that are currently provided.
For commenters providing new estimates of GWPs for the proposed
compounds for inclusion in Table A-1, we request that the commenter
submit the following types of scientific data and analyses to support
the estimated GWP:
(1) Data and analysis related to the low-pressure gas phase
infrared absorption spectrum of the compound;
(2) Data and analysis related to reaction mechanisms and rates such
as photolysis and reaction with atmospheric components such as hydroxyl
radicals (OH), ozone (O3), carbon monoxide (CO), and water;
(3) Radiative transfer analyses that integrate the lifetime and
infrared absorption spectrum data to calculate the GWP; or,
(4) Published or unpublished studies of the GWP of the compound.
The EPA intends to review and consider additional information
submitted during the public comment period to assess the proposed GWPs
and consider other accurate estimates of the GWP for each compound. We
anticipate requesting comment on additional compounds in a separate
action.
2. Other Technical Corrections and Proposed Amendments to Subpart A
In addition to the proposed amendments to global warming potentials
in Table A-1, we are also proposing corrections and other
clarifications to certain provisions of subpart A of Part 98. The more
substantive corrections, clarifying, and other amendments to subpart A
are found here. Additional minor corrections are discussed in the Table
of Revisions to this rulemaking (see Docket ID No. EPA-HQ-OAR-2012-
0934).
The EPA is proposing to revise the reporting requirements of 40 CFR
98.3(c)(1). Section 98.3(c)(1) requires reporting of the physical
address of the facility where the emissions occur (not the parent
company address). Some facilities do not have a physical street address
assigned to them and their mailing address is not co-located with their
facility operations. In order to more accurately report the physical
location of these facilities, the EPA is proposing that those without a
physical address at their operations site provide latitude and
longitude coordinates instead. This proposed addition is not intended
as an option for any facility whose physical address coincides with
their facility operations. It also is not intended for use by suppliers
and importers and/or exporters covered by Part 98, or facilities
reporting under subpart W in the natural gas distribution (40 CFR
98.230(a)(8)) or onshore petroleum and natural gas production (40 CFR
98.230(a)(2)) industry segments.
We are proposing to add a requirement to 40 CFR 98.3(c)(13) for all
facilities with a power generating unit to report the facility Office
of the Regulatory Information System (ORIS)
[[Page 19815]]
code for each power generation unit. The proposed amendment would
facilitate the verification of emissions information received by the
EPA. The EPA is also proposing to add the following definition for ORIS
code in 40 CFR 98.6 for clarity, ``ORIS Code'' means the unique
identifier assigned to each power plant in the National Electric Energy
Data System (NEEDS). The ORIS code is a four digit number assigned by
the Energy Information Administration (EIA) at the U.S. Department of
Energy to power plants owned by utilities.''
We are proposing to add a provision to 40 CFR 98.3(c)(11) to
include instructions for the reporting of a United States parent
company legal name and address. The proposed amendment would specify
that a facility or supplier must use the reporting instructions found
in e-GGRT when reporting a parent company. The proposed amendment would
facilitate verification of the emissions reported by allowing the EPA
to provide a common naming convention through e-GGRT that would be used
to easily identify parent companies and to accurately attribute GHG
emissions to the correct parent companies. Instructions regarding
reporting of parent company name and address have been posted to the
docket for this action (See docket ID no. EPA-HQ-OAR-2012-0934).
Additionally, we are proposing to amend 40 CFR 98.3(h)(4) to
clarify the provisions for requesting an extension of the 45-day period
for submission of revised reports in 40 CFR 98.3(h)(1) and (2).
Specifically, we are clarifying the timing requirements for approval or
denial of the automatic 30-day extension and any subsequent extensions
provided in 40 CFR 98.3(h)(4). The proposed amendments would require
reporters to submit a request for any additional extension beyond the
30-day automatic extension at least 5 business days prior to the
expiration of the initial 30-day extension. If the request demonstrates
that it is not practicable to submit the data or information needed to
resolve a potential reporting error following the 30-day automatic
extension, the Administrator may approve an additional extension
request. The proposed amendment would provide a reasonable timeline for
reporters to submit extension requests and for the EPA's collection and
verification of reported data.
We are proposing to add a definition of fluidized bed combustor
(FBC) to 40 CFR 98.6. The definition is necessary to be consistent with
the proposed addition of FBC-specific N2O emission factors
for coal, waste anthracite (culm), and waste bituminous (gob) to Table
C-2.
Finally, we are proposing revisions to the definitions of three
terms in subpart A: degasification system, ventilation well or shaft,
and ventilation system. These terms are used only in subpart FF,
Underground Coal Mines, and are proposed to be revised to more closely
align with common terminology used in the coal mining industry.
B. Subpart C--General Stationary Fuel Combustion Sources
We are proposing revisions to the requirements of 40 CFR part 98,
subpart C (General Stationary Fuel Combustion Sources) to clarify the
use of the Tier methodologies and to update high heat value (HHV) and
emission factors. The more substantive corrections, clarifying, and
other amendments to subpart C are found here. Additional minor
corrections are discussed in the Table of Revisions to this rulemaking
(see Docket ID No. EPA-HQ-OAR-2012-0934).
First, we are proposing to amend 40 CFR 98.33(b)(1) to expand the
use of the Tier 1 methodology in one situation that currently requires
the use of the Tier 3 methodology. Generally, subpart C requires the
use of the Tier 3 methodology for combustion units that are greater
than 250 million Btus per hour for all fuels listed in Table C-1, and,
for fuels not listed in Table C-1 if the fuel provides 10 percent or
more of the annual heat input to the unit. To reduce the monitoring
burden of determining carbon content of Table C-1 fuels that are used
in relatively small amounts annually, we are proposing a change to 40
CFR 98.33(b)(1) that will allow the Tier 1 methodology to be used for
Table C-1 fuels that are combusted in a unit with a maximum rated heat
input capacity greater than 250 million Btus per hour, if the fuel
provides less than 10 percent of the annual heat input to the unit.
We are proposing changes to Table C-1 to update the HHV and
emission factors for several fuels and to add emission factors for culm
and gob. The EPA received a number of comments and questions through
the GHGRP Help Desk with suggestions for improvements to these factors.
We researched these factors to ensure the most scientifically valid
values were reflected. An analysis of the proposed changes to Table C-1
as a result of this research can be found in the memorandum ``Review
and Evaluation of 40 CFR Part 98 CO2 Emission Factors for
EPW07072 TO 45,'' available in Docket ID No. EPA-HQ-OAR-2012-0934.
In response to a Petition for Rulemaking (``Sierra Club
Petition''),\29\ the EPA evaluated establishing separate (from the
parent coal) CO2 emission factors for culm and gob in Table
C-1. The EPA is proposing the addition of culm and gob to Table C-1.
These separate entries have been added to clarify that the Table C-1
CO2 emission factors for anthracite coal and bituminous coal
should be used for culm and gob, respectively. Because the heating
value of culm or gob is variable and quite different from the parent
anthracite or bituminous coals, the EPA is proposing that the default
heating values in Table C-1 for anthracite and bituminous may not be
used for culm and gob. The changes to Table C-1 specify that the HHV
for culm or gob must be measured according to the Tier 2 Methodology.
Our analysis and development of emission factors can be found in the
memorandum ``Emission Factor Updates for Fluidized Bed Boilers and
Other Revisions to Tables C-1 and C-2 of 40 CFR Part 98--Summary''
available in Docket Id. No. EPA-HQ-OAR-2012-0934. Because the Tier 1
Methodology allows the use of default HHVs from Table C-1, we
[[Page 19816]]
propose revising 40 CFR 98.33(b)(1) to prohibit use of the Tier 1
Methodology when estimating the emissions from combustion of culm or
gob. With these revisions and those proposed with respect to fluidized
bed combustors in this Section II.B., infra, we believe that we have
fully addressed the Petition for Rulemaking.
---------------------------------------------------------------------------
\29\ Letter from Craig Holt Segall, Sierra Club Environmental
Law Program, on behalf of the Sierra Club, Center for Biological
Diversity, Clean Air Task Force, Clean Wisconsin, the Kentucky
Environmental Foundation, the Minnesota Center for Environmental
Advocacy, and the Natural Resources Defense Council to Lisa Jackson,
U.S. EPA. Petition for Rulemaking To Correct Emission Factors in the
Mandatory Greenhouse Gas Reporting Rule. October 28, 2010.
---------------------------------------------------------------------------
Table 4 of this preamble shows a summary of the proposed Table C-1
revisions, and major changes are explained below.
Table 4--Proposed Changes to Table C-1 to Subpart C--Default CO2 Emission Factors and High Heat Values for
Various Types of Fuel
----------------------------------------------------------------------------------------------------------------
Current values Proposed values
----------------------------------------------------------------------------------------------------------------
Fuel type Default high heat Default CO2
--------------------------------- value emission factor Default high heat Default CO2
---------------------------------------- value emission factor
Coal and coke mmBtu/short ton kg CO2/mmBtu
----------------------------------------------------------------------------------------------------------------
Anthracite...................... 25.09............. 103.54............ No change......... 103.69
Waste Anthracite (Culm)......... .................. .................. See footnote 1.... 103.69
Bituminous...................... 24.93............. 93.40............. No change......... 93.28
Waste Bituminous (Gob).......... .................. .................. See footnote 1.... 93.28
Subbituminous................... 17.25............. 97.02............. No change......... 97.17
Lignite......................... 14.21............. 96.36............. No change......... 97.72
Coal Coke [Fuel type changed 24.80............. 102.04............ No change......... 113.67
from ``coke''].
Mixed (Commercial sector)....... 21.39............. 95.26............. No change......... 94.27
Mixed (Industrial coking)....... 26.28............. 93.65............. No change......... 93.90
Mixed (Industrial sector)....... 22.35............. 93.91............. No change......... 94.67
Mixed (Electric Power sector)... 19.73............. 94.38............. No change......... 95.52
----------------------------------------------------------------------------------------------------------------
Natural gas mmBtu/scf kg CO2/mmBtu .................. ..................
----------------------------------------------------------------------------------------------------------------
(Weighted U.S. Average)......... 1.028 x 10-3...... 53.02............. 1.026 x 10-3...... 53.06
Petroleum products mmBtu/gallon...... kg CO2/mmBtu...... .................. ..................
----------------------------------------------------------------------------------------------------------------
Used Oil........................ 0.135............. 74.00............. 0.138............. No change
Liquefied petroleum gases (LPG). 0.092............. 62.98............. No change......... 61.71
Propane......................... 0.091............. 61.46............. No change......... 62.87
Propylene....................... 0.091............. 65.95............. No change......... 67.77
Ethane.......................... 0.069............. 62.64............. 0.068............. 59.60
Ethylene........................ 0.100............. 67.43............. 0.058............. 65.96
Isobutane....................... 0.097............. 64.91............. 0.099............. 64.94
Isobutylene..................... 0.103............. 67.74............. No change......... 68.86
Butane.......................... 0.101............. 65.15............. 0.103............. 64.77
Butylene........................ 0.103............. 67.73............. 0.105............. 68.72
Natural Gasoline................ 0.110............. 66.83............. No change......... 66.88
Petrochemical Feedstocks........ 0.129............. 70.97............. 0.125............. 71.02
Unfinished Oils................. 0.139............. 74.49............. No change......... 74.54
Heavy Gas Oils.................. 0.148............. 74.92............. No change......... No change
Crude Oil....................... 0.138............. 74.49............. No change......... 74.54
----------------------------------------------------------------------------------------------------------------
Other fuels-solid............... mmBtu/short ton kg CO2/mmBtu .................. ..................
----------------------------------------------------------------------------------------------------------------
Tires........................... 26.87............. 85.97............. 28.00............. No change
----------------------------------------------------------------------------------------------------------------
Biomass fuels--solid mmBtu/short ton kg CO2/mmBtu .................. ..................
----------------------------------------------------------------------------------------------------------------
Wood and Wood Residuals(dry 15.38............. 93.80............. 17.48............. No change
basis) [Fuel Type description
changed from Wood and Wood
Residuals].
Solid Byproducts................ 25.83............. 105.51............ 10.39............. No change
----------------------------------------------------------------------------------------------------------------
Biomass fuels--gaseous mmBtu/scf kg CO2/mmBtu ..................
----------------------------------------------------------------------------------------------------------------
Landfill Gas [Fuel type 0.841 x 10-3...... 52.07............. 0.485 x 10-3...... No change
description changed from Biogas
(captured methane).
Other Biomass Gases [New Fuel .................. .................. 0.655 x 10-3...... 52.07
type added].
----------------------------------------------------------------------------------------------------------------
Biomass Fuels--Liquid mmBtu/gallon kg CO2/mmBtu .................. ..................
----------------------------------------------------------------------------------------------------------------
Biodiesel....................... 0.128............. 73.84............. Deleted Duplicate.
----------------------------------------------------------------------------------------------------------------
----------------------------------------------------------------------------------------------------------------
Note: ``No change'' indicates no changes to the current value. Additional footnotes have been added to the
table.
[[Page 19817]]
The changes include a change to the HHV for wood and wood
residuals. The HHV in Table C-1 for Wood and Wood Residuals is a wet
basis value that assumes a moisture content of 12 percent. GHGRP
reporters have indicated that they use wood fuel with highly variable
moisture content, and so the existing factor results in calculation
inaccuracies of CO2 emissions from burning this fuel. These
reporters have requested that the EPA provide HHVs for a range of
moisture contents for wood fuel. In order to address this issue, we are
proposing an addition to Table C-1 for ``Wood and Wood Residuals on a
dry basis,'' with a footnote containing an equation that can be used to
adjust the value for any moisture content. Reporters can then calculate
a HHV for use in Equation C-1 using the moisture content of their
facility specific fuel. We are also proposing a change to Table C-1
that replaces the one HHV for ``Biogas (captured methane)'' with values
for two types of biogas: ``Landfill Gas'' and ``Other Biomass Gases.''
The CH4 content of landfill gas (approximately 50 percent)
is typically lower than the CH4 concentration in digester
gas (approximately 65 percent), and the proposed emission factors
reflect these concentration values.
Revisions are proposed to the HHV and emission factors for the
individual components of liquid petroleum gases (LPG) including
propane, propylene, ethane, ethylene, isobutane, isobutylene, butane,
and butylene. Since the HHV for these LPGs are presented on the basis
of million Btu per gallon, and these compounds are gases under standard
conditions, the heating value must be presented using a stated
temperature and pressure. For all LPG except ethylene, we are proposing
estimates of HHV at 60 degrees Fahrenheit ([deg]F) and saturation
pressure. For ethylene, since it cannot be liquefied above 48.6[deg]F,
we have selected a value for HHV that is determined at 41[deg]F
(slightly under the critical temperature) and the corresponding
saturation pressure. The emission factors for these compounds have also
been updated using the proposed HHV and the fraction of carbon
contained in the compound.
We are proposing a correction to the emission factor for coke
because it appears that the emission factor currently in Table C-1 was
inadvertently listed as the emission factor for petroleum coke. We have
also changed the name in Table C-1 to ``coal coke'' to differentiate
this substance from ``petroleum coke,'' which has a different HHV and
EF. We are also proposing updated emission factors for the four types
of coal and the four listed factors for mixed coals based on the most
recent version of the factors used in the Inventory.
The HHV for the biomass fuel ``solid byproducts'' would be revised
to reflect the average of the solid byproducts consumed by the
facilities that reported HHV in the 1999 survey conducted by the Energy
Information Administration. The proposed value is presented on a wet
basis, and is more consistent with other biomass fuels. Based on our
research, we are also proposing minor changes to the HHV and/or
emission factors for the following substances: natural gas, used oil,
petrochemical feedstocks, and tires. Other proposed changes to Table C-
1 include updates to emission factors and HHV based on our latest
research and to standardize conversion factors. These corrections are
discussed in the memorandum ``Review and Evaluation of 40 CFR Part 98
CO2 Emission Factors for EPW07072 TO 45'' (see Docket ID No.
EPA-HQ-OAR-2012-0934).
We are also proposing to revise 40 CFR 98.33(e)(3)(iv). The method
in 40 CFR 98.33(e)(3)(iv) for calculating biogenic CO2
emissions from municipal solid waste (MSW) combustion requires the use
of a default factor for the biogenic share of CO2. We are
proposing a change to the default factor used to determine the annual
biogenic CO2 emissions from MSW from 0.6 to 0.55 to reflect
trends in waste composition. The complete analysis of this change can
be found in the memorandum ``Review and Evaluation of 40 CFR Part 98
CO2 Emission Factors for EPW07072 TO 45,'' available in
Docket ID No. EPA-HQ-OAR-2012-0934.
The EPA received a Petition for Reconsideration and Rulemaking from
the American Forest & Paper Association (AF&PA) and the American Wood
Council (AWC) on November 16, 2012 (hereafter referred to as ``AF&PA
Petition'').\30\ The AF&PA Petition included a recent study containing
new methane (CH4) and nitrous oxide (N2O)
emissions test data in support of a request that EPA revise the
CH4 and N2O emission factors in Subparts AA and C
for combustion of spent pulping liquor and wood residuals. The EPA
reviewed the basis for the current emission factors, integrated the
emissions test data provided by Petitioners with previously available
data, and is proposing to update the spent pulping liquor and wood
residual combustion emission factors in subparts AA and C,
respectively.
---------------------------------------------------------------------------
\30\ Letter from Paul Noe, American Forest & Paper Association,
and Robert Glowinski, American Wood Council, to Lisa Jackson, U.S.
EPA. Petition for Reconsideration of 40 CFR Part 98 Subparts C and
AA; Petition for Rulemaking To Revise 40 CFR Part 98 Subparts C and
AA; Request for Correction Under Information Quality Act. November
16, 2012.
---------------------------------------------------------------------------
Table 5 of this preamble summarizes the proposed Table C-2
revisions, and major changes are explained below.
Table 5--Proposed Changes to Table C-2 to Subpart C-Default CH4 and N2O Emission Factors for Various Types of
Fuel
----------------------------------------------------------------------------------------------------------------
Current values Proposed values
----------------------------------------------------------------------------------------------------------------
Default CH4 Default N2O Default CH4 Default N2O
Fuel type emission factor emission factor emission factor emission factor
----------------------------------------------------------------------------------------------------------------
Coal and Coke (All fuel types in 1.1 x 10-02....... 1.6 x 10-03....... 1.1 x 10-02....... 1.6 x 10-03
Table C-1) \1\ (Footnote Added).
Anthracite for FBCs only \2\.... N/A............... N/A............... 1.1 x 10-02....... 1.6 x 10-01
Waste Anthracite (Culm) for FBCs N/A............... N/A............... 1.1 x 10-02....... 4.0 x 10-01
only \2\.
Bituminous for FBCs only \2\.... N/A............... N/A............... 1.1 x 10-02....... 1.3 x 10-01
Waste Bituminous (Gob) for FBCs N/A............... N/A............... 1.1 x 10-02....... 2.9 x 10-01
only \2\.
Subbituminous for FBCs only \2\. N/A............... N/A............... 1.1 x 10-02....... 6.5 x 10-02
Lignite for FBCs only \2\....... N/A............... N/A............... 1.1 x 10-02....... 1.1 x 10-01
Fuel Gas........................ N/A............... N/A............... 3.0 x 10-03....... 6.0 x 10-04
[[Page 19818]]
Biomass Fuels--Solid (All fuel 3.2 x 10-02....... 4.2 x 10-03....... 3.2 x 10-02....... 4.2 x 10-03
types in Table C-1, except wood
and wood residuals) (Added to
parenthetical: ``except wood
and wood residuals'').
Wood and wood residuals......... .................. .................. 7.2 x 10-3........ 3.6 x 10-3
Biomass Fuels-Gaseous (All fuel 3.2 x 10-03....... 6.3 x 10-04....... 3.2 x 10-03....... 6.3 x 10-04
types in Table C-1) Changed
category from ``Biomass''.
----------------------------------------------------------------------------------------------------------------
N/A = No current emission factor available.
\1\ Use of the default emission factors for the coal and coke category may not be used to estimate emissions
from combusting anthracite, waste anthracite, bituminous, waste bituminous, subbituminous, or lignite coal
burned in an FBC.
\2\ Use of these default emission factors is required for FBCs burning the specified coal type.
Note: Those employing this table are assumed to fall under the IPCC definitions of the ``Energy Industry'' or
``Manufacturing Industries and Construction''. In all fuels except for coal the values for these two
categories are identical. For coal combustion, those who fall within the IPCC ``Energy Industry'' category may
employ a value of 1g of CH4/mmBtu.
Specifically, based on our analysis of this emissions test data, we
are proposing to add a row for wood and wood residuals in Table C-2
that contains CH4 and N2O emission factors
addressing those submitted to EPA with the AF&PA Petition. We
integrated that data with previously available emissions test data in
order to consider all of the information available to us in developing
the new default emission factors for wood and wood residuals. Our
analysis of the test data can be found in the memorandum ``Kraft
Pulping Liquor and Woody Biomass Methane (CH4) and Nitrous
Oxide (N2O) Emission Factor Literature Review'' available in
Docket Id. No. EPA-HQ-OAR-2012-0934.
We are also proposing to add coal, culm, and gob N2O
emission factors to Table C-2 specific to fluidized bed combustors. As
referenced above in response to the Sierra Club Petition, the EPA
reviewed multiple studies that indicate that N2O emissions
from fluidized bed combustors burning coal, culm, and gob are
significantly higher than from conventional combustion technologies.
The EPA agrees our analysis and development of emission factors
(including a discussion of emission factors for culm and gob) can be
found in the memorandum ``Emission Factor Updates for Fluidized Bed
Boilers and Other Revisions to Tables C-1 and C-2 of 40 CFR Part 98--
Summary'' available in Docket Id. No. EPA-HQ-OAR-2012-0934.
We are proposing to add ``fuel gas'' to Table C-2 of subpart C to
address a program gap discovered through the verification process.
Because fuel gas is not currently included in Table C-2, instructions
are included in subparts X and Y to use the default CH4 and
N2O emission factors for ``Petroleum (All fuel types in
Table C-1)'' to calculate CH4 and N2O emissions
from fuel gas combustion. However, for facilities that do not report
under subpart X or Y, there is currently no requirement to calculate
CH4 and N2O emissions from fuel gas combustion.
The proposed revision addresses this unintentional gap. As a result,
subpart C reporters would be required to report CH4 and
N2O emissions from fuel gas combustion. Fuel gas is defined
at 40 CFR 98.6 as ``gas generated at a petroleum refinery or
petrochemical plant and that is combusted separately or in any
combination with any type of gas.''
C. Subpart H--Cement Production
We are proposing one revision to the reporting requirements of 40
CFR part 98, subpart H (Cement Production). The current Part 98,
published on October 30, 2009, provides that facilities subject to
subpart H report the monthly cement production from each kiln at the
facility for verification of reported emissions. In the preamble to the
Technical Corrections, Clarifying, and Other Amendments to Certain
Provisions of the Mandatory Greenhouse Gas Reporting Rule (75 FR 66434,
October 28, 2010), the EPA stated its intent to change the cement
production reporting requirements under 40 CFR 98.86 to require annual,
facility-wide cement production instead of monthly, kiln-specific
cement production (75 FR 66440). Reporting cement production on a kiln-
specific basis is inconsistent with cement plant manufacturing
practices, because kilns produce clinker (an intermediate product in
cement manufacturing) and do not make cement. Although it was obviously
the EPA's intention to revise the rule accordingly, inadvertently, this
change was not reflected in the rule. This change is also consistent
with the requirement in 40 CFR 98.86(b)(3), which requires facilities
without continuous emissions monitoring systems (CEMS) to report annual
cement production at the facility. Therefore, we are proposing to amend
40 CFR 98.96(a)(2) to require reporting of facility-wide cement
production.
D. Subpart K--Ferroalloy Production
We are proposing two corrections to subpart K of Part 98
(Ferroalloy Production). First, we are proposing to revise Equation K-3
of subpart K to correct the equation. The equation in the current Part
98 does not include a conversion factor from kilograms to metric tons.
Therefore, we are proposing to correct Equation K-3 to revise the
numerical term ``2000/2205'' to ``2/2205'' to account for this
conversion.
Next, we are proposing to amend 40 CFR 98.116(e) to require the
reporting of the annual process CH4 emissions (in metric
tons) from each electric arc furnace (EAF) used for the production of
any ferroalloy listed in Table K-1 of subpart K of Part 98. Per 40 CFR
98.113(d), ferroalloy production facilities are currently required to
calculate CH4 emissions from each EAF used for the
production of ferroalloys listed in Table K-1. Facilities are currently
required to report CH4 emissions for EAFs where a CEMS is
used to measure emissions. However, the requirement to report emissions
of CH4 from EAFs where the carbon mass balance procedure is
used to measure emissions was erroneously omitted from the current Part
98. The proposed amendments are necessary for
[[Page 19819]]
consistent reporting of CH4 emissions from all ferroalloy
production facilities. Because facilities must already monitor and
calculate emissions of CH4 from each EAF, the proposed
amendment would not impose any additional burden on reporters. The
proposed data reporting element reflects aggregated annual information
that is currently gathered by reporters.
E. Subpart L--Fluorinated Gas Production
Under subpart L of Part 98 (Fluorinated Gas Production), the EPA is
proposing to extend temporary, less detailed reporting requirements for
fluorinated gas producers for an additional year. In a final rule
published on August 24, 2012, the EPA promulgated temporary, less
detailed reporting requirements for reporting years 2011 and 2012 (77
FR 51477). As discussed in that final rule, this was intended to allow
the EPA time to evaluate concerns raised by the producers that EPA
release of the more detailed reporting required by the 2010 final rule
would reveal trade secrets, and to consider how the rule might be
changed to balance these concerns with the need to obtain the data
necessary to inform the development of future GHG policies and
programs. The proposed extension would require the same less detailed
reporting for reporting year 2013 as for reporting years 2011 and 2012.
The extension would allow the EPA, as well as stakeholders, to consider
the various options for reporting emissions under subpart L in
conjunction with EPA's on-going evaluations regarding reporting inputs
to emission equations for subpart L, whose reporting deadline was
deferred until 2015. Fluorinated gas producers and other commenters
have often noted that whether or not disclosure of a particular data
element poses confidentiality concerns depends on the other data that
would be required to be reported and/or disclosed. The extension would
allow the various potential reporting requirements and confidentiality
determinations to be considered simultaneously.
F. Subpart N--Glass Production
We are proposing several clarifying revisions to subpart N of Part
98 (Glass Production). The more substantive corrections, clarifying,
and other amendments to subpart N are found here. Additional minor
corrections are discussed in the Table of Revisions (see Docket ID No.
EPA-HQ-OAR-2012-0934).
We are proposing to revise the monitoring methods used to measure
carbonate-based mineral mass-fractions to allow for more accurate
measurement methods and to add flexibility for reporters. The current
Part 98 requires that such measurements are based on sampling using
ASTM D3682-01 (Reapproved 2006) Standard Test Method for Major and
Minor Elements in Combustion Residues from Coal Utilization Processes
or ASTM D6349-09 Standard Test Method for Determination of Major and
Minor Elements in Coal, Coke, and Solid Residues from Combustion of
Coal and Coke by Inductively Coupled Plasma--Atomic Emission
Spectrometry. However, we have determined that industry consensus
standards that specify analysis by X-ray fluorescence (e.g., ASTM C25-
11 Standard Test Methods for Chemical Analysis of Limestone, Quicklime,
and Hydrated Lime and ASTM C1271-99 Standard Test Method for X ray
Spectrometric Analysis of Lime and Limestone) are more accurate than
ASTM D6349-09, which uses inductively coupled plasma or ASTM D3682-01,
which uses atomic absorption. Therefore, we are proposing to revise 40
CFR 98.144(b) to specify that reporters determining the carbonate-based
mineral mass fraction must use sampling methods that specify X-ray
fluorescence. We are proposing to remove ASTM D6349-09 and ASTM D3682-
01 from the requirements in 98.144(b). The proposed amendment would
allow reporters flexibility in choosing a sampling method (since
multiple X-ray fluorescence methods are available) while ensuring that
more accurate available measurement methods are applied. For
measurements made in the emission reporting year 2013 or prior years,
reporters would continue to have the option to use ASTM D6349-09 and
ASTM D3682-01. The EPA is not proposing to have reporters revise
previously submitted annual reports. These facilities would have the
option, but not be required, to use the newly proposed option for the
reports submitted to EPA in 2013.
G. Subpart O--HFC-22 Production and HFC-23 Destruction
The EPA is proposing clarifying amendments and other corrections to
Subpart O (HFC-22 Production and HFC-23 Destruction); the more
substantive corrections, clarifying, and other amendments to Subpart O
are found in this section. Additional minor corrections to Subpart O
are discussed in the Table of Revisions (see Docket ID No. EPA-HQ-OAR-
2012-0934).
We are proposing to add a sentence to 40 CFR 98.156(c) to clarify
how to report the HFC-23 concentration at the outlet of the destruction
device in the event that the concentration falls below the detection
limit of the measuring device. The provisions of 40 CFR 98.156(c)
require facilities that destroy HFC-23 to report the concentration of
HFC-23 measured at the outlet of the destruction device during the
facility's annual HFC-23 concentration measurements at the outlet of
the destruction device. However, if the concentration during the
measurements falls below the detection limit of the measuring device,
the facility will not be able to report a specific concentration. The
proposed sentence clarifies that in this situation, facilities are
required to report the detection limit of the measuring device and that
the concentration was below that detection limit.
H. Subpart P--Hydrogen Production
We are proposing several clarifying revisions to subpart P of Part
98 (Hydrogen Production). The more substantive corrections, clarifying,
and other amendments to subpart P are found here. Additional minor
corrections are discussed in the Table of Revisions (see Docket ID No.
EPA-HQ-OAR-2012-0934).
We are proposing to revise 40 CFR 98.163(b) to clarify that when
the fuel and feedstock material balance approach is followed, the
average carbon content and molecular weight for each month used in
Equations P-1, P-2, or P-3 may be based on analyses performed annually
or analyses performed more frequently than monthly (based on the
requirements of 40 CFR 98.164(b)). If the carbon content or molecular
weight measurements are performed annually, reporters would use the
annual value as the monthly average. If the analyses are performed more
often than monthly, then the reporter would use the arithmetic average
of these values as the monthly average. The term definitions in
Equations P-1, P-2, and P-3 currently refer to the ``results of one or
more analyses for month n''; however, the monitoring frequencies
specified at 40 CFR 98.163(b)(2), (b)(3) and (b)(4) range from weekly
to annually, so this clarification is necessary to align these
requirements. Further, we are proposing to revise the term definitions
in Equations P-1, P-2, and P-3 to remove references to ``one or more
analyses'' since multiple analyses in a month are not always required,
as described above.
We are also proposing to modify 40 CFR 98.164(b)(5) to reduce
burden by adding flexibility to the fuel and feedstock analysis
requirements, consistent with EPA's original intent
[[Page 19820]]
and subpart C (40 CFR 98.34(a)(6), 40 CFR 98.34(b)(4)), and subpart X
(40 CFR 98.244(b)(4)(xiii)). The proposed change allows a facility to
analyze fuels and feedstocks using chromatographic analysis, whether
continuous or non-continuous.
We are proposing to move recordkeeping requirements currently
included in 40 CFR 98.164 (Monitoring and QA/QC requirements) to 40 CFR
98.167 (Records that must be retained). Specifically, 40 CFR 98.164(c)
and (d) will be moved to new paragraphs 40 CFR 98.167(c) and (d).
Finally, we are proposing to revise 40 CFR 98.166(a)(2) and (a)(3) to
remove the requirement to report hydrogen and ammonia production for
all units combined. The individual unit production is already reported
and can be summed to obtain the production for all units combined.
I. Subpart Q--Iron and Steel Production
We are proposing multiple amendments to subpart Q of Part 98 (Iron
and Steel Production) to provide clarification for certain provisions
and calculation methods. The more substantive corrections, clarifying,
and other amendments to subpart Q are found here. Additional minor
corrections are discussed in the Table of Revisions (see Docket ID No.
EPA-HQ-OAR-2012-0934).
We are proposing to amend the definition of the iron and steel
production source category in subpart Q, 40 CFR 98.170, to include
direct reduction furnaces not co-located with an integrated iron and
steel manufacturing process. Reporters are required to report
CO2 emissions from direct reduction furnaces under 40 CFR
98.172(c), and it was the EPA's intent for this reporting requirement
to cover all direct reduction furnaces; however, the inclusion of
direct reduction furnaces not co-located with an integrated iron and
steel manufacturing process was inadvertently excluded from 40 CFR
98.170. The proposed change corrects that omission. This change impacts
only one facility currently operating in the United States and that
facility is already reporting under Part 98. We do not anticipate this
change will impose a burden on additional existing reporters.
The EPA is proposing to amend Equation Q-5 in subpart Q to account
for the use of gaseous fuels in EAFs. Many EAF operators use
supplemental natural gas for melting scrap in the furnace. One facility
that provided input to the EPA on this issue meets approximately 20
percent of its energy requirement with natural gas. Because natural gas
combustion products can constitute a significant portion of
CO2 emissions from EAFs, we are proposing to modify Equation
Q-5 by adding terms to account for the amount of gaseous fuel combusted
and the carbon content of the gaseous fuel. We are also proposing to
amend Equation Q-5 by correcting the term ``Cf'' to
``Cflux'' and the term ``Cc'' to
``Ccarbon'' to match those presented in the definitions, and
to add a closing bracket at the end of the equation.
Additionally, we are proposing to revise 40 CFR 98.173(d) to
clarify when the Tier 4 calculation methodology must be used to
calculate and report combined stack emissions. The proposed amendment
would clarify that the Tier 4 calculation methodology would be used
(and emissions would be reported under subpart C of Part 98) if the GHG
emissions from a taconite indurating furnace, basic oxygen furnace,
non-recovery coke oven battery, sinter process, EAF, decarburization
vessel, or direct reduction furnace are vented through a stack equipped
with a CEMS that complies with the Tier 4 methodology in subpart C of
this part, or through the same stack as any combustion unit or process
equipment that reports CO2 emissions using a CEMS that
complies with the Tier 4 Calculation Methodology in subpart C. The
amendment is necessary to clarify that facilities using either shared
or dedicated CEMS must use the appropriate subpart C calculation
methodology for determining emissions.
We are also proposing to amend 40 CFR 98.174(c)(2) by removing the
term ``furnace'' from the statement ``For the furnace exhaust,''
because decarburization vessels are not furnaces. We are also proposing
to amend 40 CFR 98.174(c)(2) by dividing (c)(2) into two separate sub
paragraphs to separately specify the sampling time for continuously
charged EAFs. Newer and more efficient EAFs use the
``Consteel[supreg]'' process, which involves continuous, rather than
batch, scrap feed. Thus, ``production cycles'' may be an ambiguous term
for reporters who operate a continuous EAF, and could be interpreted to
require lengthy test periods as a single production cycle could extend
for several days during which steel was continuously tapped. Therefore,
we are proposing to remove the term ``production cycles'' for
continuous EAFs and provide owners or operators with the option of
sampling for a period spanning at least three hours.
We are proposing to amend 40 CFR 98.175(a) to clarify that 100
percent data availability is not required for process inputs and
outputs that contribute less than one percent of the total mass of
carbon into or out of the process. In accordance with 40 CFR
98.174(b)(4), reporters do not collect the monthly mass or annual
carbon content of inputs or outputs that contribute less than one
percent of the total mass of carbon into or out of the process.
Therefore, reporters are not required to estimate missing data for
these inputs. Similarly, we are proposing to amend 40 CFR 98.176(e) by
clarifying that the reporting requirements of 40 CFR 98.176(e) do not
apply to process inputs and outputs that contribute less than one
percent of the total mass of carbon into or out of the process.
J. Subpart X--Petrochemical Production
We are proposing changes to subpart X of Part 98 (Petrochemical
Production). In addition, we are providing flexibility for reporters
and clarifying the calculation methodology, monitoring and reporting
requirements, missing data procedures and other provisions under the
rule. The more substantive corrections, clarifying, and other
amendments to subpart X are found here. Additional minor corrections
are discussed in the Table of Revisions to this rulemaking (see Docket
ID No. EPA-HQ-OAR-2012-0934).
We are proposing to revise 40 CFR 98.242(b)(2) to clarify that
reporters using the mass balance option for a petrochemical process are
not to report emissions from the combustion of petrochemical off-gas in
any combustion unit, regardless of whether or not the combustion unit
is part of the petrochemical process unit. Subpart X currently states
that emissions of CO2, CH4, and N2O
from only supplemental fuels (i.e., not from the combustion of process
off-gas) burned in a combustion unit are reported under subpart C of
Part 98 (General Stationary Fuel Combustion Sources). However, this
requirement applies only to combustion units that are within the
petrochemical process unit because the definition of supplemental fuel
applies only to combustion within the process unit. Reporters may
interpret this to mean that combustion units not within the
petrochemical process unit should report emissions from combustion of
petrochemical off-gas. This would lead to double counting since these
emissions are already accounted for in the mass balance calculation.
The proposed amendment would avoid possible double counting by
specifying that emissions from the combustion of petrochemical process
off-gas in combustion units outside the process unit also are not to be
reported under subpart C.
[[Page 19821]]
We are proposing a change to the calculation methodology in 40 CFR
98.243(b) for CH4 and N2O emissions from burning
process off-gas for reporters using the CEMS method to determine
CO2 emissions. The proposed calculation method is consistent
with the calculation approach for CEMS-monitored sources in subpart C
but should not increase burden because Tier 4 units can use the best
available information to estimate cumulative annual heat input (see 40
CFR 98.33(c)(4)(i), 40 CFR 98.33(c)(4)(ii)(C)). The proposed
calculation method would require reporters to use Equation C-10 of
subpart C of Part 98. Reporters would use the cumulative annual heat
input from combustion of the off-gas (mmBtu) and proposed fuel gas
emission factors from Table C-2 to calculate emissions of
CH4 and N2O. The proposed fuel gas emission
factors in Table C-2 are the same as the ``Petroleum'' factors
previously referenced by subpart X, but we determined that a separate
entry for fuel gas is needed for other reasons, as described in Section
II.B of this preamble.
We are proposing to modify both 40 CFR 98.243(c)(3) and 40 CFR
98.244(b)(4) to allow subpart X reporters that use the mass balance
calculation method to obtain carbon content measurements from a
customer of the product. Subpart X currently requires petrochemical
manufacturers to determine product carbon contents from their own
analyses. This change would provide additional flexibility for sources
to obtain the carbon content measurement, and it is consistent with the
current option that allows petrochemical manufacturers to obtain the
carbon content of feedstocks from feedstock suppliers.
We are proposing a change to 40 CFR 98.243(c)(4) for the
alternative sampling requirements for feedstocks and products when the
composition is greater than 99.5 percent of a single compound for
reporters using the mass balance calculation method. Currently, the
alternative can only be used during periods of normal operation and
when the product meets specifications. We are proposing changes that
will allow the alternative method to be used during all times that the
average monthly concentration is above 99.5 percent. The proposed
changes would allow greater flexibility for reporters.
For reporters using the mass balance calculation method in 40 CFR
98.243(c)(5), we are proposing to revise definitions for five of the
terms in Equation X-1. First, we are proposing to clarify that the term
``Cg'' includes streams containing CO2 recovered
for sale or use in another process, which is consistent with the
current definition of the term ``(CCgp)i,n''.
Second, proposed changes to the terms
``(Fgf)i,n'' and
``(Pgp)i,n'' would clarify that the inputs for
gaseous feedstock and products may be measured on either a mass basis
or a volume basis. Finally, we are proposing clarifications to the
terms for molecular weight of gaseous feedstocks and products
(``(MWf)i'' and ``(MWp)i'')
to specify that molecular weight is to be determined monthly, which is
consistent with the monitoring frequency specified in 40 CFR
98.243(c)(1).
We are proposing to modify the test method description for
chromatographic analysis in 40 CFR 98.244(b)(4)(xiii) to remove the
word ``gas.'' The proposed change would clarify that a chromatograph
other than a gas chromatograph may be used. We are also proposing to
modify 40 CFR 98.244(b)(4)(xv) to allow additional methods for the
analysis of carbon black feedstock oils and carbon black products. This
section of subpart X currently specifies that a reporter may use an
industry standard practice for such feedstocks and products. The
proposed changes would provide additional flexibility by also allowing
the use of a method published by a consensus-based standards
organization (i.e., a published method that is not already specifically
listed in 98.244(b)(4)). For clarity, the proposed amendments also
would list known consensus-based standards organizations and add a
requirement for facilities to document the standard method that they
use in the facility monitoring plan required under 40 CFR 98.3(g)(5).
We are proposing to add a requirement under 40 CFR 98.244(c) to
clarify the monitoring and quality assurance requirements for flares.
Following implementation of Part 98, the EPA received questions
concerning the monitoring and quality assurances requirements for
flares because while the rule refers to subpart Y for flare emission
calculation methods, it does not specify monitoring and quality
assurance requirements. As a result, we are clarifying the requirements
for flares to specify that facilities must conduct monitoring and
quality assurance in accordance with 40 CFR 98.254. The proposed
monitoring requirements for flares harmonize subpart X with other
subparts under Part 98.
We are proposing to clarify the missing data procedures in 40 CFR
98.245 for missing feedstock and product flow rates and missing
feedstock and product carbon contents. This section of subpart X
currently specifies that reporters are to develop substitute values for
these parameters using the same procedures as for missing fuel carbon
contents as specified in 40 CFR 98.35. The proposed amendment clarifies
that the procedures for missing fuel carbon contents in 40 CFR
98.35(b)(1) are to be used only for missing feedstock and product
carbon contents, and the procedures for missing fuel usage in 40 CFR
98.35(b)(2) are to be used to develop substitute values for missing
feedstock and product flow rates. We are also proposing to add missing
data requirements for missing flare data and for missing molecular
weights for gaseous feedstocks and products. The amendment would
require reporters to develop substitute values for missing molecular
weights using the procedures for missing fuel carbon contents as
specified in 40 CFR 98.35(b)(1), and substitute values for missing
flare data would be developed using the procedures in 40 CFR 98.255(b)
and (c). We are proposing these additional missing data procedures so
that reporters do not have to contact the EPA individually for guidance
on how to proceed in the absence of instructions in the rule. We also
expect that these changes will promote consistency both among subpart X
reporters and between subpart X reporters and other reporters (e.g.,
subpart Y reporters).
We are proposing two amendments to clarify the reporting
requirements of 40 CFR 98.246(a)(6) for reporters using the mass
balance method. This section of subpart X currently requires a reporter
to report the name of each method listed in 40 CFR 98.244 that is used
to determine a measured parameter. In addition, when a method is not
listed in 40 CFR 98.244 (i.e., for flow or mass measurements), the
reporter is required to provide a description of the manufacturer's
recommended method. The only methods listed in 40 CFR 98.244 are
methods for determining carbon content or molecular weight, and they
are all in paragraph (b)(4) of 40 CFR 98.244. Thus, one proposed
amendment to clarify 40 CFR 98.246(a)(6) would require reporters to
report the name of each method that is used to determine carbon content
or molecular weight in accordance with 40 CFR 98.244(b)(4). The current
requirement to provide a description of manufacturer's recommended
method has been interpreted in various ways, and a wide variety of
information has been provided in reports to date. To simplify this
reporting requirement,
[[Page 19822]]
reduce burden, and promote consistency among reporters, the second
proposed change would require reporters to describe each type of device
used to determine flow or mass (e.g., flow meter or weighing device)
and identify the method used to determine flow or mass for each device
in accordance with 40 CFR 98.244(b)(1) through (b)(3). Methods could be
identified by method number, title, or other descriptor.
We are proposing to revise 40 CFR 98.246(a)(8) to specify that
reporters using the mass balance calculation method must identify
combustion units outside of the petrochemical process unit that burned
process off-gas. This section of subpart X currently requires
identification of each combustion unit that burned both process off-gas
and supplemental fuel. Supplemental fuel is defined as fuel burned in a
petrochemical process that is not produced within the process itself.
Thus, the current language in 40 CFR 98.246(a)(8) requires
identification of only those combustion units within a petrochemical
process unit that burn off-gas from the process. The purpose of the
proposed change is to extend this requirement to combustion units that
combust fuel gas generated by the petrochemical process but are not
part of the petrochemical process. This additional information is
needed to allow us to verify correct reporting of fuel gas in subpart
C.
We are proposing to revise 40 CFR 98.246(a)(9) for reporters using
the alternative to sampling and analysis for carbon content as
specified in 40 CFR 98.243(c)(4) of the mass balance calculation
method. One of the proposed changes would clarify the units of time to
report in (days) for periods during which off-specification product was
produced. A second proposed revision would eliminate reporting of the
volume or mass of off-specification products produced. If a facility is
complying with 40 CFR 98.243(c)(4) for a product and produces off-
specification products so that the average monthly purity does not fall
below 99.5 percent, then the facility need not report the amount of
off-specification product. However, if the average monthly purity does
fall below 99.5 percent, the facility must use the carbon content
procedures in 40 CFR 98.243(c)(3) for the off-specification product,
and must report the amount and carbon content of the off-specification
product under 40 CFR 98.246(a)(4). The proposed revision would reduce
the burden on reporters.
We are proposing several changes to the CEMS reporting requirements
in 40 CFR 98.246(b)(4), (b)(5), and (b)(6) to improve the accuracy of
emissions attributed to subpart X sources, clarify requirements, and
reduce burden. We would revise 40 CFR 98.246(b)(4) to specify that for
each CEMS monitoring location where CO2 emissions from
either the process or combustion of off-gas from the process are
measured, the facility must provide an estimate of the fraction of the
total CO2 emissions that are attributable to the
petrochemical process unit, based on engineering judgment. Subpart X
currently requires this reporting for process off-gas combustion
emissions but not for process emissions. We need both to correctly
determine the quantity of CEMS location emissions attributable to the
petrochemical process unit. We would remove the requirements in 40 CFR
98.246(b)(4) and (b)(5) to report CO2, CH4, and
N2O emissions from each CEMS location because this
requirement is also specified in 40 CFR 98.36(c)(2), which is
referenced from 40 CFR 98.246(b)(2). Similarly, we would remove the
requirement to report the aggregated total emissions from all CEMS
locations because the EPA will calculate sums from the reported values
for individual CEMS locations, as necessary. In 40 CFR 98.246(b)(5) we
would also remove the requirements to report inputs to Equation C-8
because we are proposing to replace the requirement to use Equation C-8
with a requirement to use Equation C-10, as noted previously in this
section. Instead of the Equation C-8 inputs, reporters would report the
total annual heat input for Equation C-10, as required in 40 CFR
98.35(c)(2). Finally, we are proposing to remove the requirement to
identify each stationary combustion unit that burns petrochemical
process off-gas. We use combustion unit identifications to help verify
the distribution of emissions reported under subparts C and X for
reporters that use the mass balance method. The identifications are not
needed for reporters that use CEMS because all emissions from each
combustion unit that burns process off-gas are reported under subpart
X. On balance, we expect that these changes will reduce the reporting
burden.
K. Subpart Y--Petroleum Refineries
We are proposing changes, technical corrections and clarifying
amendments for subpart Y of Part 98 (Petroleum Refineries). The more
substantive corrections, clarifying, and other amendments to subpart Y
are found here. Additional minor corrections are discussed in the Table
of Revisions (see Docket ID No. EPA-HQ-OAR-2012-0934).
In conjunction with the addition of fuel gas to Table C-2 as
discussed in Section II.B of this preamble, we are proposing revisions
to subpart Y to change the reference to Table C-2 at 40 CFR
98.253(b)(2) and (b)(3) from ``Petroleum Products'' to ``Fuel Gas'' for
calculation of CH4 and N2O from combustion of
fuel gas. We are also proposing to revise 40 CFR 98.252(a) to remove
the reference to the default emission factors for ``Petroleum (All fuel
types in Table C-1)'' in Table C-2. Because the emission factors for
Petroleum Products and Fuel Gas are identical, this will not change the
result of any emission calculation.
We are proposing to revise 40 CFR 98.253(f)(4) and the terms
``FSG'' and ``MFc'' in Equation Y-12 to clarify
the calculation methods for sulfur recovery plants to address both on-
site and off-site sulfur recovery plants. We are also proposing changes
to the reporting requirements in 40 CFR 98.256(h) to clarify the
reporting requirements for on-site and off-site units. The proposed
revisions would clarify the requirements that should apply to on-site
versus off-site sulfur recovery plants.
We are proposing to clarify 40 CFR 98.253(j) regarding when
Equation Y-19 must be used for calculation of CH4 and
CO2 emissions. The proposed change clarifies that Equation
Y-19 must be used to calculate CH4 emissions if the reporter
elected to use the method in 40 CFR 98.253(i)(1), and may be used to
calculate CO2 and/or CH4 emissions, as
applicable, if the reporter elects this method as an alternative to the
methods in paragraphs (f), (h), or (k) of 40 CFR 98.253. We are also
proposing to clarify reporting requirements to 40 CFR 98.256(j) and (k)
to specify that when Equation Y-19 is used for asphalt blowing
operations or delayed coking units, the facility must report the
relevant information required under 40 CFR 98.256(l)(5) rather than all
of the reporting elements in 40 CFR 98.256(l).
L. Subpart Z--Phosphoric Acid Production
We are proposing an additional requirement, minor corrections, and
clarifications to subpart Z of Part 98 (Phosphoric Acid Production).
The more substantive corrections, clarifying, and other amendments to
subpart Z of Part 98 are discussed in this section. Additional minor
corrections are discussed in the Table of Revisions (see Docket ID No.
EPA-HQ-OAR-2012-0934).
The terminology used in the introductory text of 40 CFR
[[Page 19823]]
98.263(b)(1)(ii) and definition of the term ``CO2n,'' could
be interpreted as meaning that the method for sampling carbon content
of rock represented direct CO2 emissions from the process,
which was not the EPA's intention. While the equation calculates
CO2 emissions from a process line, the input values obtained
from the measurements of grab samples are CO2 content of the
rock. Therefore, we are proposing to amend 40 CFR 98.263(b)(1)(ii) and
the description of ``CO2n,i'' to indicate that the sampling
method provides CO2 content, and not emissions.
We are also proposing to revise 40 CFR 98.266(b) to require that
the annual report must include the annual phosphoric acid production
capacity (tons), rather than the annual permitted phosphoric acid
production capacity. Through implementation of the rule, the EPA has
learned that not all facilities have a ``permitted'' production
capacity. The EPA is proposing to revise this requirement to report
annual production capacity, as opposed to permitted production
capacity, in the current Part 98.\31\ The proposed change acknowledges
that not all phosphoric acid production facilities have a permitted
production capacity. Additionally, not all facilities produce to the
permitted capacity. This change is necessary to ensure that the EPA
collects consistent annual production capacity data and will provide a
better characterization of the relationship between industry production
and emissions.
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\31\ See Table 9 of this preamble for the EPA's proposed data
category assignment and confidentiality determination for this data
element.
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We are also proposing to amend 40 CFR 98.266 to add a requirement
to report the number of times missing data procedures were used to
estimate the CO2 content of the phosphate rock. The proposed
requirement is consistent with 40 CFR 98.264(b), which allows for
determination of either inorganic carbon content or CO2
content.
M. Subpart AA--Pulp and Paper Manufacturing
We are proposing changes to subpart AA of Part 98 (Pulp and Paper
Manufacturing) to revise default emission factors and clarify the
information that must be reported. The more substantive corrections,
clarifying, and other amendments to subpart AA of Part 98 are discussed
in this section. Additional minor corrections are discussed in the
Table of Revisions (see Docket ID No. EPA-HQ-OAR-2012-0934).
We are proposing to amend 40 CFR 98.273(a)(3), 40 CFR 98.276(e) and
Equation AA-1 to remove the references to site-specific emissions
factors because there are no methods or requirements in subpart AA for
deriving the site-specific GHG emission factors for biomass combustion.
We are proposing revisions to the emission factors shown in Tables
AA-1 and AA-2 to correct format errors that occurred in the printing of
the rule in the CFR. Specifically, in Table AA-1, the CH4
and N2O emission factors were intended to apply to each
fuel. However, when printed in the Federal Register, lines were added
to separate each row/fuel, and this format change created the
appearance that the factors apply only to the first fuel listed in the
table. To correct this error, we are proposing to insert the
CH4 and N2O emission factors for each individual
fuel. Today's proposed changes will make the rule conform to Tables AA-
1 and AA-2 as they originally were proposed in the April 10, 2009
Federal Register (74 FR 16692). A similar error occurred with Table AA-
2. In addition, the Kraft Lime Kiln N2O factors were
inadvertently omitted in the printing of Table AA-2; it was intended to
be zero (0) for all fuels in Table AA-2 (as proposed to be amended in
the August 11, 2010 Federal Register (75 FR 48811)).
In addition to correcting formatting errors, we are proposing
revisions to the CH4 and N2O emission factors for
pulping liquor in Table AA-1 based on emissions test data made
available to us for eight U.S. recovery furnaces in the AF&PA Petition
as discussed above. Our analysis of that data confirms that the
information contained in the AF&PA Petition is more robust and relevant
for U.S. recovery furnaces than the original Table AA-1 emission
factors which were previously adopted from a literature review.\32\
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\32\ See the memorandum in the docket titled, ``Kraft Pulping
Liquor and Woody Biomass Methane (CH4) and Nitrous Oxide (N2O)
Emission Factor Literature Review.''
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We are also proposing additional changes to Table AA-2 to (1) Amend
the title to remove the reference to fossil fuel since the table
contains a biogenic fuel as well (biogas); (2) specify that the
emission factors for residual and distillate oil apply for any type of
residual (no. 5 or 6) or distillate (no. 1, 2 or 4) fuel oil to clarify
our intent that the emissions factors apply to all grades of these fuel
types; and (3) add a row to specify that the Table C-2 emission factor
for CH4 and the Table C-2 emission factors for
CH4 and N2O may be used, respectively, for
ancillary lime kilns and calciners combusting fuels (e.g., propane,
used oil, and lubricants) that were not previously listed in Table AA-
2. The Technical Support Document for Subpart AA from the final Part 98
\33\ explains that the operating temperatures in rotary lime kilns
appear to be too high for appreciable formation of N2O, so
an emission factor of zero is proposed for N2O from
ancillary fuel combustion in pulp mill lime kilns.
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\33\ Available at: http://www.epa.gov/ghgreporting/documents/pdf/archived/tsd/TSD Pulp_and_Paper 2_11_09.pdf.
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We are proposing to amend 40 CFR 98.276(k) to clarify the EPA's
intent regarding the annual pulp and/or paper production information
that must be reported. Since publication of the rule, we have received
questions from the industry about what this requirement means and the
units of measure to use for reporting pulp production. Hence, we are
proposing to amend the rule to clarify that the annual production
information must consist of the production of air-dried, unbleached
virgin pulp produced onsite during the reporting year and the
production of paper products exiting the paper machine(s) during the
reporting year, prior to application of any off-machine coatings.\34\
Greenhouse gas emissions from pulp and paper operations reported under
subpart AA are dependent on the amount of pulp produced. Reporting the
total annual production of air-dried unbleached virgin pulp provides a
common reporting basis for all types of pulp mills regardless of
production processes (e.g., bleaching, secondary fiber pulping, and
paper making) that happen downstream of the virgin pulping process
where the GHG emissions are generated.
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\34\ See the memorandum ``Proposed data category assignments and
confidentiality determinations for new and substantially revised
data elements in the proposed `2013 Revisions to the Greenhouse Gas
Reporting Rule and Confidentiality Determinations for New or
Substantially Revised Data Elements''' (hereafter referred to as
``Confidentiality Determinations Memorandum'') (Docket Id. No. EPA-
HQ-OAR-2012-0934) for the proposed category assignments and
confidentiality determinations for new and revised data elements.
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N. Subpart BB--Silicon Carbide Production
We are proposing several revisions to subpart BB of Part 98
(Silicon Carbide Production). The more substantive corrections,
clarifying, and other amendments to subpart BB of Part 98 are discussed
in this section. Additional minor corrections are discussed in the
Table of Revisions (see Docket ID No. EPA-HQ-OAR-2012-0934).
[[Page 19824]]
We are proposing to revise 40 CFR 98.282(a) to remove the
requirement for silicon carbide production facilities to report
CH4 emissions from silicon carbide process units or
furnaces. We are proposing to revise 40 CFR 98.283(d) to remove the
CH4 calculation methodology. The current CH4
calculation methodologies in subpart BB overestimate the emissions of
CH4 from silicon carbide facilities because the equations do
not take into consideration the destruction of CH4
emissions. Because these emissions are typically controlled, emissions
from these facilities are minimal, and the EPA has determined that the
requirement to report CH4 emissions is not necessary to
understand the emissions profile of the industry.
Reporters must continue to monitor and report CO2
emissions from silicon carbide process units and production furnaces.
We are proposing to revise 40 CFR 98.283 so that CO2
emissions are to be calculated and reported for all process units and
furnaces combined. The EPA intended in the final Part 98 (October 30,
2009) to require reporting from all silicon carbide process units and
production furnaces, as specified in 40 CFR 98.282. However, 40 CFR
98.283 states that ``You must calculate and report the annual process
CO2 emissions from each silicon carbide process unit or
production furnace using the procedures in either paragraph (a) or (b)
of this section.'' The proposed correction would revise 40 CFR 98.283
for consistency with the reporting requirements of 40 CFR 98.286 and
reduce burden by combining all emissions.
O. Subpart DD--Electrical Transmission and Distribution Equipment Use
We are proposing two substantive corrections to subpart DD
(Electrical Transmission and Distribution Equipment Use) in this
section. We are proposing to revise 40 CFR 98.304(c)(1) and (c)(2) to
correct the accuracy and precision requirements for weighing cylinders.
In the current Part 98, the subpart DD regulatory text for 40 CFR
98.304(c)(1) and (c)(2) presents the required scale accuracies as ``2
pounds of the scale's capacity.'' The scale accuracy requirement for
subpart DD was intended to be ``2 pounds of true weight,'' as expressed
in the ``Technical Support Document: Emissions from Electric Power
Equipment Use'' and ``EPA's Response to Public Comments: Subpart DD:
Electric Transmission and Distribution Equipment Use'' \35\, and the
preamble to the final Part 98 (74 FR 56260, October 30, 2009). The
proposed amendments would make 40 CFR 98.304(c)(1) and (c)(2)
consistent with the EPA's intent.
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\35\ See http://www.epa.gov/ghgreporting/reporters/subpart/dd.html.
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P. Subpart FF--Underground Coal Mines
We are proposing multiple amendments to subpart FF of Part 98
(Underground Coal Mines) to clarify certain provisions and equation
terms, harmonize reporting requirements, and improve verification of
annual GHG reports. The more substantive corrections, clarifying, and
other amendments to subpart FF of Part 98 are discussed in this
section. Additional minor corrections are discussed in the Table of
Revisions (see Docket ID No. EPA-HQ-OAR-2012-0934).
We are proposing to revise the terminology in subpart FF in
response to questions submitted by reporters. Reporters have noted that
ventilation does not take place through wells, but rather mine
ventilation system shafts or vent holes, and degasification systems do
not use shafts, but rather wells or gob gas vent holes. Reporters have
also stated that mine ventilation air is not flared, rather it is
destroyed using a ventilation air methane (VAM) oxidizer. Therefore we
are proposing to revise provisions in 40 CFR 98.320(b), 40 CFR
98.322(b) and (d), 40 CFR 98.323(c), and 40 CFR 98.324(b) and (c) to
adopt terminology that more accurately reflects industry operations.
We are also proposing to revise the reporting requirements of
subpart FF to include additional data elements that will allow the EPA
to verify the data submitted, perform a year to year comparison of the
data, and assess the reasonableness of the data reported.\36\ The data
elements are readily available to the reporter and would not require
additional data collection or monitoring or significantly increase the
reporting burden. The additional data elements are included in the
proposed revised 40 CFR 98.326(h), (i), (j), (o), (r), and new
requirements (t) and (u) and include: The moisture correction factor
used in the emissions equations, units of measure for the volumetric
flow rates reported, method of determining the gas composition, the
start date and close date of each well or shaft, the number of days the
well or shaft was in operation during the reporting year, and the
amount of CH4 routed to each destruction device. We are also
proposing to add a reporting requirement (40 CFR 98.326(u)) for the
reporting mines to provide the Mine Safety and Health Administration
(MSHA) identification. This identification number will allow the EPA to
easily identify the facility for verification and comparison of the
Inventory data with GHGRP data. The reporting requirements have also
been updated to harmonize with changes to the calculation methods as
itemized in the Table of Revisions (see Docket ID No. EPA-HQ-2-12-
0934).
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\36\ See Table 9 of this preamble for the proposed category
assignments and confidentiality determinations for each proposed
data element.
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Q. Subpart HH--Municipal Solid Waste Landfills
We are proposing multiple revisions to 40 CFR part 98, subpart HH
(Municipal Solid Waste Landfills) to clarify equations and amend
monitoring requirements to reduce burden for reporters. The more
substantive corrections, clarifying, and other amendments to subpart HH
are discussed in this section. Additional minor corrections are
discussed in the Table of Revisions (see Docket ID No. EPA-HQ-OAR-2012-
0934).
We are proposing to amend the definition of the degradable organic
carbon (DOC) term for Equation HH-1 to indicate that the DOC values for
a waste type must be selected from Table HH-1. When we originally
proposed subpart HH in April of 2009, Equation HH-1 applied to both MSW
and industrial waste landfills. When we finalized Subpart HH for MSW
landfills only, the definition of the DOC term allowed for the default
value from Table HH-1 or measurement data, if available. Although we
included measurement methods for determining site-specific DOC values
for industrial waste streams within Subpart TT, we do not consider that
these laboratory methods are suitable for determining the DOC for MSW
landfills in subpart HH because of the variability and heterogeneity of
MSW.
The EPA may take into consideration the usage of site-specific DOC
values for MSW landfills in Equation HH-1 if suitable measurement
methods are available. We specifically request comment from reporters
who have used measurement methods for determining DOC. We request that
the commenter provide information on the type of waste streams for
which measurement methods were used, the analytical method used to
determine DOC, and procedures used to ensure that the samples tested
were representative of the waste stream tested for different years. We
also note that, if measurements of DOC are made for different years,
the DOC variable in Equation HH-1 should be a function of
[[Page 19825]]
the year the waste is placed in the landfill. As currently written, the
DOC term in Equation HH-1 is a constant for a given waste type and is
not a function of the disposal year. We therefore also request comment
on the need to revise Equation HH-1 and the definition of DOC to allow
DOC to be a different value for different years that a waste is placed
in the landfill.
We are proposing to amend the definition of the term ``F'' in
Equation HH-1 (fraction by volume of CH4 in the landfill
gas) to further clarify that this term should be corrected to zero
percent (0%) oxygen. Unlike the concentration of CH4 in the
landfill gas as measured for use in Equation HH-4, the term F is more
accurately defined as the fraction of the dissimilated carbon that is
metabolized to CH4. Some landfill gas collection systems may
draw ambient air into the collected landfill gas, thereby diluting the
concentration of CH4 in the landfill gas. The proposed
amendment is needed to correct measurements of CH4
concentrations made in gas collection systems (or elsewhere) for
ambient air dilution so that the resultant value of F more closely
matches the fraction of degraded carbon that is generated as
CH4.
We are also proposing to revise the definition of parameter ``N''
in Equation HH-4 and the provisions of 40 CFR 98.343(b)(2)(i), (ii),
(iii)(A), and (iii)(B). We received comments from landfill owners and
operators that the requirement to sample CH4 concentrations
weekly was burdensome, particularly for closed landfills, and
unnecessary because the CH4 concentrations did not vary
appreciably over the year. Some landfill owners and operators provided
EPA with their weekly flow and CH4 concentration data for
the 2011 reporting year for 395 unique landfills. We reviewed and
analyzed the data and determined that reducing the CH4
concentration monitoring frequency from weekly to monthly would
increase the overall uncertainty of a landfill's CH4
recovery from 8 percent to 10.5 percent. (See
``Review of Weekly Landfill Gas Volumetric Flow and Methane
Concentrations,'' October 18, 2012, in Docket ID No. EPA-HQ-OAR-2012-
0934.) It is reasonable to conclude that the on-going annual costs
associated with monitoring CH4 concentrations monthly would
be approximately one-fourth the cost of monitoring weekly. Thus,
landfill owners can realize a significant savings in their monitoring
costs while not significantly increasing the uncertainty in the
calculated CH4 recovery. Based on the data provided by the
landfill owners and operators and our analysis of that data, we are
proposing to revise the minimum monitoring frequency from weekly to
monthly.
We are proposing to amend the oxidation fraction default value used
in Equations HH-5, HH-6, HH-7, and HH-8 of subpart HH. We received
comments from landfill owners and operators that the oxidation fraction
default value of 10 percent that is required to be used in these
equations is too low and that many landfills exhibit much higher
oxidation fractions. Over the past several years, numerous U.S.
landfills have been tested to estimate the oxidation fraction; the
newly tested landfills have been predominately landfills with gas
collection systems and clay soil or ``other soil mixture'' covers. We
reviewed the oxidation study data and analyzed Subpart HH data to
evaluate various options for revising the default oxidation fraction.
Based on our review, we agree that the 10 percent soil oxidation
fraction likely underestimates the amount of methane oxidized in the
surface soil layer when the landfill gas flow through the soil surface
is reduced, as is the case for landfills with gas collection systems.
We considered a revised single default oxidation fraction or a default
oxidation fraction based on the type of cover soil used at the
landfill, but these defaults do not take in account the key variable,
which is the methane flux rate entering the surface soil layer. Based
on our analysis, we are proposing three different default oxidation
fractions depending on the methane flux ``bin,'' found in new proposed
Table HH-4. For cases where the methane flux is projected to be high
(greater than 70 grams/m\2\/day), the default oxidation fraction
remains as 10 percent. For cases where the methane flux is projected to
be low (less than 10 grams/m\2\/day), the default proposed oxidation
fraction is 35 percent. For cases with moderate methane flux rates (10
to 70 grams/m\2\/day), the proposed default oxidation fraction is 25
percent. We are also proposing to add requirements in paragraph
98.346(h) and paragraphs 98.346(i)(8), (10), and (11) for facilities to
report the oxidation fraction used in each of Equations HH-5, HH-6, HH-
7, and HH-8.\37\ We have concluded that this binned approach provides a
more realistic estimate of the role of methane oxidation in the surface
soil on the methane emissions than the single default oxidation
fraction. We are including Table HH-4 to reference these values. Table
HH-4 also provides a calculation method to determine the methane flux
rate to be used for determining the oxidation fraction when Equations
HH-5, HH-6, HH-7, or HH-8 are used. Reporters under subpart TT will
also use Table HH-4 when Equation TT-6 is used to determine the methane
generation adjusted for oxidation. For further information regarding
our analysis of methane oxidation fractions, see ``Review of Methane
Flux and Soil Oxidation Data'', December 7, 2012, in Docket ID No. EPA-
HQ-OAR-2012-0934.
---------------------------------------------------------------------------
\37\ The EPA is proposing category assignments and
confidentiality determinations for these new and revised data
elements in the Confidentiality Determinations Memorandum (Docket
Id. No. EPA-HQ-OAR-2012-0934).
---------------------------------------------------------------------------
We are also proposing to amend Equations HH-6, HH-7, and HH-8 and
surrounding text to generalize these equations in the event that the
landfill contains multiple landfill gas collection system measurement
locations and/or multiple destruction devices. When there is a single
landfill gas measurement location, these equations are identical to the
existing equations. However, the existing equations were inadequate to
calculate CH4 emissions at landfills with gas collection
systems that have multiple measurement locations and/or multiple
destruction devices. In addition to the revisions proposed to clarify
equation term definitions when multiple measurement locations or
destruction devices are used, we are also proposing to revise the
definition of the fDest term for Equation HH-6 and HH-8 to
clarify that the fraction of hours the destruction device was operating
should be calculated as the number of operating hours for the device
divided by the hours that gas flow as sent to the device.
We are also proposing to amend the first sentence in 40 CFR
98.345(c) to revise ``in reporting years'' to ``in the reporting year''
to clarify that the missing data procedures are for a reporting year
and that reporters do not need to report substitute data information
for years prior to the current reporting year, thereby reducing the
burden on reporters.
Finally, we are proposing to revise 40 CFR 98.346(d)(1) and (e) to
move the reporting elements pertaining to the methane correction factor
(MCF) from paragraph (d)(1) to paragraph (e) because MCF is not a
function of the waste type. This amendment eliminates the duplicative
reporting requirements for MCF and its related reporting elements
(i.e., reporters would no longer be required to report this information
for each waste type).
[[Page 19826]]
R. Subpart LL--Suppliers of Coal-based Liquid Fuels
We are proposing multiple revisions to 40 CFR part 98, subpart LL
(Suppliers of Coal-based Liquid Fuels) to clarify requirements and
amend data reporting requirements to reduce burden for reporters. This
section includes the more substantive corrections, clarifying, and
other amendments to subpart LL. Additional minor corrections are
discussed in EPA's Table of Revisions (see Docket ID No. EPA-HQ-OAR-
2012-0934).
To reduce burden, we are proposing to remove the requirements at 40
CFR 98.386(a)(1), (a)(5), (a)(13), (b)(1), and (c)(1) for each
facility, importer, and exporter to report the annual quantity of each
product or natural gas liquid on the basis of the measurement method
used. Reporters would continue to report the annual quantities of each
product or natural gas liquid in metric tons or barrels at 40 CFR
98.386(a)(2), (a)(6), (a)(14), (b)(2), and (c)(2). We are also
retaining the requirement to report a complete list of methods used to
measure the annual quantities reported for each product or natural gas
liquid.
S. Subpart MM--Suppliers of Petroleum Products
We are proposing several revisions to 40 CFR part 98, subpart MM
(Suppliers of Petroleum Products) to clarify requirements and amend
data reporting requirements to reduce burden for reporters. This
section includes the more substantive corrections, clarifying, and
other amendments to subpart MM. Additional minor corrections are
discussed in the Table of Revisions (see Docket ID No. EPA-HQ-OAR-2012-
0934).
We are proposing to clarify the equation term for
``Producti'' at 40 CFR 98.393(a)(2) to exclude those
products that entered the refinery but are not reported under 40 CFR
98.396(a)(2). We are proposing harmonizing changes to 40 CFR 98.394(b)
to make the equipment calibration requirements for petroleum products
suppliers consistent with other Part 98 calibration requirements. The
requirements for equipment calibration in 40 CFR part 98, subpart A
(General Provisions) allow for postponement of calibrations for units
and processes that operate continuously with infrequent outages. We are
proposing similar provisions be incorporated into the subpart MM
equipment calibration requirements. The proposed changes would also
provide flexibility for reporters meeting the equipment calibration
requirements.
As with the proposed changes to subpart LL, in order to reduce
burden for reporters, we are proposing to remove the requirements of 40
CFR 98.396(a)(1), (a)(5), (a)(13), (b)(1), and (c)(1) for each
facility, importer, and exporter to report the annual quantity of each
petroleum product or natural gas liquid on the basis of the measurement
method used. Reporters would continue to report the annual quantities
of each petroleum product or natural gas liquid in metric tons or
barrels at 40 CFR 98.396(a)(2), (a)(6), (a)(14), (b)(2), and (c)(2). We
are also retaining the requirement to report a complete list of methods
used to measure the annual quantities reported for each product or
natural gas liquid.
In order to reduce the recordkeeping and reporting burden, the EPA
is proposing to eliminate the reporting requirement for individual
batches of crude oil feedstocks. The reporting requirements for crude
oil at 40 CFR 98.396(a)(20) are proposed to be changed to require only
the annual quantity of crude oil. We are also proposing to eliminate
the requirement to measure the API gravity and the sulfur content of
each batch of crude oil at 40 CFR 98.394(d). We are also proposing to
remove the requirement at 40 CFR 98.394(a)(1) that a standard method by
a consensus-based standards organization be used to measure crude oil
on site at a refinery, if such a method exists. Other associated
changes to the rule to harmonize with this change include removing the
definition of ``batch,'' removing the procedures for estimating missing
data for determination of API gravity and sulfur content at 40 CFR
98.395(c), and the recordkeeping requirement for crude oil quantities
at 40 CFR 98.397(b). Reporters would still be required to maintain all
the records required to support information contained in the reports as
specified at 40 CFR 98.397(a).
We are proposing to include the definitions of natural gas liquids
(NGL) and bulk NGLs in the subpart MM definitions at 40 CFR 98.397 to
clarify the distinction between NGL and bulk NGL for reporting purposes
under subpart MM. ``Natural gas liquids (NGLs)'' for purposes of
reporting under subpart MM means hydrocarbons that are separated from
natural gas as liquids through the process of absorption, condensation,
adsorption, or other methods, and are sold or delivered as
differentiated product. Generally, such liquids consist of ethane,
propane, butanes, or pentanes plus. Those subject to subpart MM are
required to report NGLs as the individual differentiated product and
are not required to conduct testing to determine additional components
(i.e., impurities) that are contained within the differentiated
product. For a mixture, the individual components should be reported.
For example, if a refinery receives a known mixture of propane and
ethane, the refiner must report the quantities of propane and ethane
individually. Undifferentiated NGLs would be reported as bulk NGLs for
subpart MM. We are also proposing to clarify the reporting requirements
for bulk NGLs and NGLs. NGLs should be reported either as
differentiated NGLs or as bulk NGLs. The requirement at 40 CFR
98.396(a)(22) is proposed to be modified to specify that NGLs reported
in 40 CFR 98.396(a)(2) should not be reported again in 40 CFR
98.396(a)(22).
Finally, we are proposing to revise the default density and
emission factors in Table MM-1 for propane, propylene, ethane,
ethylene, isobutane, isobutylene, butane, and butylene. Because these
compounds are gases under standard conditions, the default density
metric must be presented using a stated temperature and pressure. For
all compounds except ethylene, we are proposing estimates of density
and calculated emission factors at 60 degrees F and saturation
pressure, the standard temperature and pressure conditions used by
industry. For ethylene, because it cannot be liquefied above
48.6[deg]F, we have selected as a basis for the values of density and
emission factor conditions at 41[deg]F (slightly under the critical
temperature) and the corresponding saturation pressure. The current and
proposed values for default density and emission factors are included
in Table 6 of this preamble.
[[Page 19827]]
Table 6--Proposed Changes to Table MM-1 to Subpart MM of Part 98-Default Factors for Petroleum Products and
Natural Gas Liquids
----------------------------------------------------------------------------------------------------------------
Proposed Proposed
Column A: Column C: Column A: Column C:
Products density emission density emission
(metric tons/ factor (metric (metric tons/ factor (metric
bbl) tons CO2/bbl) bbl) tons CO2/bbl)
----------------------------------------------------------------------------------------------------------------
Ethane \3\...................................... 0.0866 0.2537 0.0579 0.170
Ethylene \4\.................................... 0.0903 0.2835 0.0492 0.154
Propane \3\..................................... 0.0784 0.2349 0.0806 0.241
Propylene \3\................................... 0.0803 0.2521 0.0827 0.260
Butane \3\...................................... 0.0911 0.2761 0.0928 0.281
Butylene \3\.................................... 0.0935 0.2936 0.0972 0.305
Isobutane \3\................................... 0.0876 0.2655 0.0892 0.270
Isobutylene \3\................................. 0.0936 0.2939 0.0949 0.298
----------------------------------------------------------------------------------------------------------------
\3\ The density and emission factors for components of LPG determined at 60[deg]F and saturation pressure (LPGs
other than ethylene).
\4\ The density and emission factor for ethylene determined at 41[deg]F and saturation pressure.
T. Subpart NN--Suppliers of Natural Gas and Natural Gas Liquids
The EPA is proposing multiple corrections and clarifying amendments
to the provisions of subpart NN (Suppliers of Natural Gas and Natural
Gas Liquids). The more substantive corrections, clarifying, and other
amendments to subpart NN are discussed in this section. Additional
minor corrections are discussed in the Table of Revisions (see Docket
ID No. EPA-HQ-OAR-2012-0934).
First, we are proposing to amend the definition of Local
Distribution Companies (LDCs) in 40 CFR 98.400(b) to coincide with the
definition of LDCs in 40 CFR 98.230(a)(8) (40 CFR part 98, subpart W).
For LDCs that operate in multiple states, we are proposing to clarify
that the operations in each state are considered a separate LDC. For
example, if an LDC owns and operates pipelines in two adjacent states,
the LDC is considered two separate entities both for the purpose of
determining applicability and for registering and reporting under
subpart NN. We are also proposing a revision to clarify that interstate
and intrastate pipelines delivering natural gas either directly to
major industrial users or to farm taps upstream of the local
distribution company inlet are not included in the definition of an
LDC. The proposed changes are harmonizing changes that improve the
consistency of provisions across Part 98.
We are also proposing to revise 40 CFR 98.406(b)(7).\38\ The
current subpart NN rule requires that LDCs report annual volume of
natural gas delivered to each meter registering supply equal to or
greater than 460,000 thousand standard cubic feet (Mscf) during the
calendar year. The EPA is proposing a change in the calculation and
reporting requirements that would require that if the LDC knows that a
series of meters serves one particular customer receiving a total of
greater than 460,000 Mscf during the year, the LDC would be required to
report these deliveries per customer rather than per meter. If the LDC
does not know if the series of meters serve a single customer or
multiple customers, the LDC may continue to report deliveries to
individual meters. Customers that receive over 460,000 Mscf
(approximately 25,000 Mtons CO2) for use in combustion are
required to report emissions under subpart C or subpart D. We are
proposing the change to 40 CFR 98.407(b)(7) in order to greatly
minimize double counting emissions reported under subparts C or D and
emissions that would result from natural gas supplied reported under
subpart NN from facilities that may receive a total of over 460,000
Mscf of natural gas through several meters.
---------------------------------------------------------------------------
\38\ The EPA has proposed a data category and confidentiality
determination for this revised data element. See the Confidentiality
Determinations Memorandum (Docket Id. No. EPA-HQ-OAR-2012-0934).
---------------------------------------------------------------------------
The EPA received comments that the multiple streams of natural gas
included in Equation NN-5 may have different characteristics (e.g.,
HHV). Subpart NN currently requires the use of a single emission factor
for all types of gas streams accounted for in Equation NN-5 (e.g., gas
stored, liquefied natural gas removed from storage, natural gas
received from local production). Because the characteristics of these
streams may differ, the EPA agrees that emissions associated with the
supply of natural gas would be more accurately calculated using
emission factors specific to each stream. To allow reporters the
flexibility to use different emission factors for different natural gas
streams, the EPA is proposing Equation NN-5 be replaced with two
equations, Equations NN-5a and NN-5b. The greenhouse gas quantity
associated with the net amount of natural gas that is placed into or
removed from storage during the year is proposed to be calculated using
Equation NN-5a. Emissions that would result from the combustion or
oxidation of natural gas supplied that bypassed the city gate are
proposed to be calculated using Equation NN-5b. Separating Equation NN-
5 into two equations does not impose additional burden on reporters.
LDCs already monitor the volume of gas placed into or removed from
storage separately from natural gas that bypassed the city gate.
Further, LDCs may use different emission factors in Equations NN-5a and
NN-5b, though they are not required to. The default value may be used.
Additionally, we are proposing a change to Equation NN-6 that
incorporates the two proposed NN-5 equations. With this change, all the
equation terms resulting in net additions to the CO2
quantity are added, and terms resulting in decreases to the
CO2 quantity are subtracted from the LDC's subpart NN total.
This change will make Equation NN-6 easier to understand.\39\ Finally,
the EPA has learned that o-grade as well as y-grade bulk NGLs are
fractionated by facilities subject to subpart NN. Additionally, the EPA
has learned that some fractionators strip out only a portion of the
bulk NGL stream and supply the remaining bulk NGL downstream to other
fractionators, where it is separated into its constituent products.
Therefore, the EPA is
[[Page 19828]]
proposing revisions to 40 CFR 98.406(a)(4) to add new reporting
elements that require reporting of the quantity of o-grade, y-grade,
and other types of bulk NGLs received, and the quantity not
fractionated, but supplied downstream.\40\
---------------------------------------------------------------------------
\39\ We are also proposing to revise the reporting requirements
in 40 CFR 98.406(b) in order to harmonize the reported data with the
change to the equations in subpart NN. See the Confidentiality
Determinations Memorandum (Docket Id. No. EPA-HQ-OAR-2012-0934) for
the proposed category assignments and confidentiality determinations
for new and revised data elements.
\40\ See the Confidentiality determinations Memorandum (Docket
Id. No. EPA-HQ-OAR-2012-0934) for the proposed category assignments
and confidentiality determinations for new and revised data
elements.
---------------------------------------------------------------------------
We are also proposing changes to the HHV and emission factors in
Table NN-1 and NN-2. As discussed in this preamble for subpart C and
subpart MM, we are proposing to revise the default HHV and emission
factors for the individual components of liquid petroleum gases (LPG)
including propane, ethane, isobutane, and butane. These values for
Table NN-1 and NN-2 are based on the same HHV, density and carbon share
used for the HHV and emission factors in Table C-1 and MM-1. Since
these compounds are gases under standard conditions, the default
emission factors in Table NN-1 and NN-2 (kg CO2 per MMBtu or
MT CO2 per barrel) and HHV in Table NN-1 (MMBtu per barrel)
must be presented using a density at a stated temperature and pressure.
For all these LPGs, we are proposing calculated values of HHV and
emission factors using the density of the liquid at 60[deg]F and
saturation pressure, standard temperature and pressure conditions used
by industry. The current and proposed default HHV and emission factors
are shown in Tables 7 and 8 of this preamble.
Table 7--Proposed Changes to Table NN-1 to Subpart NN of Part 98-Default Factors for Calculation Methodology 1 of This Subpart
--------------------------------------------------------------------------------------------------------------------------------------------------------
Proposed Default CO2
Fuel Default high heating value Default CO2 emission Proposed Default higher emission factor (kg CO2/
factor factor (kg CO2/MMBtu) heating value \1\ MMBtu)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Natural Gas.............................. 1.028 MMBtu/Mscf............. 53.02 1.026 MMBtu/Mscf............ 53.06
Propane.................................. 3.822 MMBtu/bbl.............. 61.46 3.84 MMBtu/bbl.............. 62.87
Normal butane............................ 4.242 MMBtu/bbl.............. 65.15 4.34 MMBtu/bbl.............. 64.77
Ethane................................... 4.032 MMBtu/bbl.............. 62.64 2.85 MMBtu/bbl.............. 59.60
Isobutane................................ 4.074 MMBtu/bbl.............. 64.91 4.16 MMBtu/bbl.............. 64.94
Pentanes plus............................ 4.620 MMBtu/bbl.............. 70.02 4.62 MMBtu/bbl.............. 70.02
--------------------------------------------------------------------------------------------------------------------------------------------------------
\1\ Conditions for higher heating values presented in MMBtu/bbl are 60[deg]F and saturation pressure.
Table 8--Proposed Changes Table NN-2 to Subpart NN of Part 98-Default Values for Calculation Methodology 2 of
This Subpart
----------------------------------------------------------------------------------------------------------------
Proposed
Default CO2 Default CO2
Fuel Unit emission value emission value
(MT CO2/Unit) (MT CO2/Unit)
\1\
----------------------------------------------------------------------------------------------------------------
Natural Gas................................... Mscf............................ 0.055 0.0544
Propane....................................... Barrel.......................... 0.235 0.241
Normal butane................................. Barrel.......................... 0.276 0.281
Ethane........................................ Barrel.......................... 0.253 0.170
Isobutane..................................... Barrel.......................... 0.266 0.270
----------------------------------------------------------------------------------------------------------------
\1\ Conditions for emission value presented in MT CO2/bbl are 60[deg]F and saturation pressure.
U. Subpart PP--Suppliers of Carbon Dioxide
We are proposing three substantive amendments to subpart PP of Part
98 (Suppliers of Carbon Dioxide) that are described in this section.
One additional minor correction is discussed in the Table of Revisions
(see Docket ID No. EPA-HQ-OAR-2012-0934).
We are proposing to amend 40 CFR 98.423(a)(3)(i) to clarify that
both capture and extraction facilities may use Equation PP-3a to
aggregate annual data from multiple flow meters. In the December 17,
2010 Technical Corrections, Clarifying, and Other Amendments to the GHG
Reporting Rule (75 FR 79092), we modified the provisions of 40 CFR
98.423(a)(3) to add Equation PP-3b to account for situations where a
CO2 stream is segregated such that only a portion is
captured for commercial application or for injection and where a flow
meter is used prior to the point of segregation; we also introduced the
two-meter approach for facilities with production process units that
capture a CO2 stream. At that time, we made a harmonizing
change and re-designated Equation PP-3 to Equation PP-3a. However, we
inadvertently limited the application of equation PP-3a to facilities
with production processes, whereas in the original promulgation,
Equation PP-3 could be used by all facilities (including those with
production wells) that have multiple streams and multiple flow meters.
In this rulemaking we are proposing to amend 40 CFR 98.423(a)(3)(i) to
clarify that facilities with CO2 production wells that
extract or produce a CO2 stream may use Equation PP-3a to
aggregate the total annual mass of CO2 from multiple
extracted streams. This clarifying change increases the reporting
flexibility for facilities with CO2 production wells by
allowing them to aggregate CO2 emissions from multiple
CO2 streams, without sacrificing the quality of data
reported.
Finally, we are proposing to amend the reporting requirements of 40
CFR 98.426(f)(10) and (f)(11), which require reporting the aggregated
annual CO2 quantities transferred to enhanced oil and
natural gas recovery or geologic sequestration. The proposed changes
would clarify that these end use application options reflect injection
of CO2 to geologic sequestration or enhanced oil recovery as
covered by 40 CFR part 98, subparts RR and UU, respectively.
[[Page 19829]]
V. Subpart QQ--Importers and Exporters of Fluorinated Greenhouse Gases
Contained in Pre-Charged Equipment or Closed-Cell Foams
We are proposing multiple revisions to 40 CFR part 98, subpart QQ
(Importers and Exporters of Fluorinated Greenhouse Gases Contained in
Pre-Charged Equipment or Closed-Cell Foams). The more substantive
corrections, clarifying, and other amendments to subpart QQ are
discussed in this section. Additional minor corrections are discussed
in the Table of Revisions (see Docket ID No. EPA-HQ-OAR-2012-0934). We
are proposing to correct the equation term ``St'' in
Equations QQ-1 and QQ-2 to clarify that the input may be mass (charge
per piece of equipment) or density (charge per cubic foot of foam, kg
per cubic foot). The proposed revision is necessary to ensure that the
input for each equation is in the correct units when the density of F-
GHG in the foam is used.
We are proposing to amend an example within the definition of
``closed-cell foam'' at 40 CFR 98.438. The revised text would read
``Closed-cell foams include but are not limited to polyurethane (PU)
foam contained in equipment, * * *'' The EPA is proposing this change
to clarify that the reporting requirements apply to devices that
contain F-GHGs in closed-cell foams even if the device is not an
``appliance'' as defined in this section. Appliances are defined as
devices that contain a fluorinated greenhouse gas refrigerant. This
change clarifies that the reporting requirements apply to equipment
such as water heaters which have closed-cell foam but no refrigerant
charge. Similarly the reporting requirements apply to refrigeration and
air conditioning equipment that contain closed-cell foam but not
refrigerants that are covered by this reporting program. As part of
this change, we are also proposing to replace the term ``appliance''
with the term ``equipment'' at 40 CFR 98.436(a)(3), (a)(4), (a)(6)(ii),
(a)(6)(iii), (b)(3), (b)(4), (b)(6)(ii), and (b)(6)(iii). This
clarification does not subject any new foams to the reporting
requirements as subpart QQ currently requires the reporting of all
fluorinated GHG closed-cell foams excluding packaging foam.
We are proposing to revise the reporting requirements for 40 CFR
98.436(a)(6)(iii) and (b)(6)(iii) to match the reported data element to
the units required to be reported. The proposed revision is a change
from ``mass in CO2e'' to ``density in CO2e.'' The
units specified for the data elements in the current subpart QQ are kg
CO2e/cubic foot, and are unchanged in this proposal.\41\
---------------------------------------------------------------------------
\41\ The EPA has proposed a data category and confidentiality
determination for these revised data elements. See the
Confidentiality Determinations Memorandum (Docket Id. No. EPA-HQ-
OAR-2012-0934).
---------------------------------------------------------------------------
We are proposing to amend the definition of ``pre-charged
electrical equipment component'' at 40 CFR 98.438. The EPA is revising
the definition to include components charged with any fluorinated
greenhouse gas. The current definition is limited to components charged
with SF6 or PFCs. The purpose of this revision is to align
the definition of a component with that of ``pre-charged electrical
equipment'' which is defined as containing a fluorinated greenhouse
gas.
We are also proposing to remove the following reporting
requirements to alleviate burden on reporters: 40 CFR 98.436(a)(5),
(a)(6)(iv), (b)(5), and (b)(6)(iv). These provisions require reporters
to supply the dates on which pre-charged equipment or closed-cell foams
were imported or exported. The EPA established these reporting
requirements to allow the agency to compare these data with shipment
manifest data from Customs and Border Protection (CBP). The EPA has
since learned that the data required under this subpart is more
specific than the data found in the manifests, and has determined that
the remaining information provided by the facilities is sufficient for
verification purposes. The EPA can compare total annual imports and
exports of appliances with reported data without needing date-specific
information. In addition, the EPA has been made aware of the burden
created by tracking and reporting each shipment by date. Many importers
and exporters do not maintain data that include the appliance charge
and foam type by date of import or export. Some of those that do
indicated to the EPA that this would result in tens of thousands of
reports. We do not believe that this level of specificity is necessary
to understand the net import and export of fluorinated greenhouse gases
within appliances and closed-cell foams. Given the burden and low
utility of this data, the EPA is proposing to remove these
requirements. The EPA is also not proposing any changes to the
recordkeeping requirements of 40 CFR 98.437 as the current requirements
do not require the records to be organized by date in this manner. We
have determined that the current recordkeeping requirements are
sufficient because they would contain a complete record of imports and
exports without requiring an aggregation of this data by date.
W. Subpart RR--Geologic Sequestration of Carbon Dioxide
We are proposing several corrections to subpart RR of Part 98
(Geologic Sequestration of Carbon dioxide). The more substantive
corrections, clarifying, and other amendments to subpart RR are
discussed in this section. Additional minor corrections are discussed
in the Table of Revisions (see Docket ID No. EPA-HQ-OAR-2012-0934).
We are proposing to add a requirement for facilities to report the
standard or method used to calculate the mass or volume of contents in
containers that is redelivered to another facility without being
injected into the well.\42\ The addition of this requirement improves
consistency within subpart RR, as it was previously only required for
facilities using flow meters but not containers. This new reporting
element would be used for verification purposes. The proposed data
element does not require additional data collection or monitoring by
reporters, and as it is not a significant change, would not add burden
to reporting entities.
---------------------------------------------------------------------------
\42\ The EPA has proposed a data category and confidentiality
determination for this revised data element. See the Confidentiality
Determinations Memorandum ``Proposed data category assignments and
confidentiality determinations for (Docket Id. No. EPA-HQ-OAR-2012-
0934).
---------------------------------------------------------------------------
X. Subpart SS--Electrical Equipment Manufacture or Refurbishment
We are proposing clarifying amendments and other corrections to
subpart SS of Part 98 (Electrical Equipment Manufacture or
Refurbishment); the more substantive corrections, clarifying, and other
amendments to subpart SS are discussed in this section. Additional
minor corrections to subpart SS are discussed in the Table of Revisions
(see Docket ID No. EPA-HQ-OAR-2012-0934).
We are proposing to harmonize 40 CFR 98.453(d) and 40 CFR
98.453(h), clarifying the options available to estimate the mass of
SF6 and PFCs disbursed to customers in new equipment. The
proposed revision does not add a new option, but clarifies the existing
estimation methods for reporters under subpart SS.
The EPA intended to provide four options for the calculation of
SF6 or PFCs charged into equipment or containers that are
sent to customers; these options are based on how the reporter
determines the mass of SF6 or PFCs in equipment or
containers. The
[[Page 19830]]
four options are monitoring the mass flow of the SF6 or PFCs
into the new equipment or cylinders using a flowmeter; weighing
containers before and after gas from containers is used to fill
equipment or cylinders; and using the nameplate capacity of the
equipment either by itself or together with a calculation of the
partial shipping charge.
The proposed changes are designed to correct inconsistencies
between paragraphs so that all options are clearly identified as
available. We are proposing to add text to 40 CFR 98.453(d) to include
the options to use the nameplate capacity of the equipment by itself
and to use the nameplate capacity along with a calculation of the
partial shipping charge; these options were inadvertently omitted from
that paragraph. The provisions of 40 CFR 98.453(h) currently state that
reporters ``must'' use the nameplate capacity of the equipment, or
calculate the partial shipping charge, to determine the mass of
SF6 or PFCs disbursed to customers in new equipment. This is
inconsistent with the language and intent of 40 CFR 98.453(d), which
was to provide facilities multiple options for determining the mass
disbursed. Therefore, we are proposing to revise 40 CFR 98.453(h) to
clarify that these calculation requirements only apply where reporters
choose to estimate the mass of SF6 or PFCs disbursed to
customers in new equipment using the nameplate capacity of the
equipment, either by itself or together with a calculation of the
partial shipping charge.
Y. Subpart TT--Industrial Waste Landfills
We are proposing several amendments to 40 CFR part 98, subpart TT
to clarify and correct calculation methods, provide additional
flexibility for certain monitoring requirements, and clarify reporting
requirements. The more substantive corrections, clarifying, and other
amendments to subpart TT are discussed in this section. Additional
minor corrections are discussed in the Table of Revisions (see Docket
ID No. EPA-HQ-OAR-2012-0934).
We are proposing to revise the definition of the term
``DOCF'' in Equation TT-1 when a 60-day anaerobic
biodegradation test is used. In Equation TT-1, ``DOCF'' is
defined as the fraction of degradable organic carbon (DOC) that is
dissimilated to landfill gas. The typical assumption is that half of
the DOC will be anaerobically dissimilated and therefore, the default
value for ``DOCF'' currently used in Equation TT-1 is 0.5.
However, the 60-day anaerobic biodegradation test effectively
determines the organic carbon content that is anaerobically
dissimilated, and as such, represents the product of the terms
``DOCX'' and ``DOCF'' within Equation TT-1.
Therefore, for facilities using the 60-day anaerobic biodegradation
test, it can be assumed that all of the measured DOC will be
dissimilated (as it was during the test), so that ``DOCF''
is 1. We are therefore proposing that the DOCF have a
default value of 1.0 for facilities using the 60-day anaerobic
biodegradation test.
We are also proposing similar revisions to Equation TT-7, which is
used to determine a waste stream-specific DOC value when a facility
performs a 60-day anaerobic biodegradation test. The DOC value from
Equation TT-7 is then used as an input to Equation TT-1 for that waste
stream. Consistent with our proposed revision of the
``DOCF'' term in Equation TT-1, ``DOCF'' equals 1
when DOC is determined using the 60-day anaerobic biodegradation test.
As such the ``1/DOCF'' term in Equation TT-7 must equal to
1, so there is no need to include this term in the Equation TT-7.
We are also proposing to delete the term ``1/
(MCDcontrol/MCcontrol)'' from Equation TT-7. This
term was erroneously included to correct the measured value of the DOC
(i.e., MCDsample/Msample) for the recovery of the
control substrate. However, after further review, the EPA determined
that the recovery of the control substrate is only used to ensure
quality control of the anaerobic biodegradation test (i.e., to verify
that the inoculum or sludge from an anaerobic sludge digester used in
the test is in fact biologically active) and is therefore not
appropriate to include as a correction term in this equation.
We are proposing to revise 40 CFR 98.464(b) and (c) to broaden the
provisions to determine volatile solids concentration for historically
managed waste streams for the purposes of 40 CFR 98.460(c)(2)(xii)
(exemption as an inert waste) so that they may also be used for
determining a site-specific DOC value for historically managed waste
streams. When we added the 60-day anaerobic biodegradation test in the
2011 Technical Corrections, Clarifying, and Other Amendments (76 FR,
73886; November 2011), we had not considered the impact of those
amendments to this section. We did not intend to prevent facilities
from using the 60-day anaerobic biodegradation test for similar waste
streams for determining if a waste stream is inert. Furthermore, if a
facility tests a similar waste stream and the waste stream is not
inert, we did not intend to prevent the facility from using that result
as the DOC value for their waste stream for purposes of calculating
CH4 generation and ultimately reporting GHG emissions. The
proposed amendments expand the provisions of this section to
determining a site-specific DOC value for historically managed waste
streams both to assess whether the waste stream qualifies as an inert
waste and to use in Equation TT-1 (even when the waste stream does not
qualify as inert).
We are proposing to amend 40 CFR 98.466(b)(1) to clarify that the
number of waste streams for which Equation TT-1 is used includes the
number of ``Inert'' waste streams disposed of in the landfill.\43\
Although ``Inert'' waste streams have a DOC of 0 and therefore do not
contribute to the facility's CH4 generation, 40 CFR
98.463(a) clearly requires the owner or operator to ``Apply Equation
TT-1 of this section for each waste stream disposed of in the landfill
* * *'' Therefore, an owner or operator of an industrial waste landfill
that is required to report the emissions must apply Equation TT-1 to
their inert waste streams and include these inert waste streams in the
number reported in 40 CFR 98.466(b)(1).
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\43\ The EPA has proposed a data category and confidentiality
determination for this revised data element. See the Confidentiality
Determinations Memorandum (Docket Id. No. EPA-HQ-OAR-2012-0934).
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As part of the 2011 Technical Corrections, Clarifying, and Other
Amendments (76 FR, 73886), we amended Equation TT-4 to become Equation
TT-4a and added Equation TT-4b for the calculation of historical waste
disposal quantities. However, we neglected to amend the reporting
requirements specific to Equations TT-4a and TT-4b in 40 CFR
98.466(c)(4). We also noted that the reporting elements associated with
Equations TT-4a or TT-4b were not waste-stream specific and therefore
did not need to be reported for each waste stream as indicated by the
introduction in 40 CFR 98.466(c). In order to eliminate duplicative
reporting requirements and to clarify the reporting requirements when
using Equations TT-4a or TT-4b, we are proposing several amendments to
40 CFR 98.466(c). First, we are proposing to revise the introductory
text in 40 CFR 98.466(c) to read ``Report the following historical
waste information'' rather than ``For each waste stream identified in
paragraph (b) of this section, report the following information.''
Second, we are proposing to move the reporting of the decay rate (k)
from paragraph (c)(1) to a new paragraph (b)(5) as this reporting
[[Page 19831]]
element is more correctly categorized under ``waste characterization
and modeling information''; we are specifically indicating that the
reporting of the decay rate (k) must be made for each waste stream (as
it was previously). Third, we are proposing to clarify that the
reporting elements for paragraphs (c)(2) and (c)(3) are for each waste
stream (as they were under previously). Fourth, we are proposing to
clarify that the reporting elements for Equation TT-4 are specific to
reporters using Equation TT-4a; these reporting elements would be
reported once for the facility's landfill rather than for each waste
stream. Fifth, we are proposing to add a new paragraph (c)(5) to this
section to delineate the reporting requirements for reporters using
Equation TT-4b; these reporting elements would also be reported once
for the facility's landfill rather than for each waste stream. We are
also proposing to amend 40 CFR 98.466(d)(3) to read ``For each waste
stream, the degradable organic carbon * * *'' rather than ``The waste
stream's degradable organic carbon * * *'' to clarify that these
reporting elements must be reported for each waste stream. \44\
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\44\ The EPA is proposing data category assignments and
confidentiality determinations for the new and substantially revised
data elements in the Confidentiality Determinations Memorandum
(Docket Id. No. EPA-HQ-OAR-2012-0934).
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To harmonize with the proposed changes to subpart HH, and in order
to more accurately reflect the amount of methane oxidized in the
surface soil layer of industrial waste landfills, we are proposing to
amend the oxidation fraction default value (``OX'') in Equation TT-6.
Reporters would be referred to newly proposed Table HH-4 to determine
the value for ``OX'' to be used in Equation TT-6. Please see Section
II.Q of this preamble for more detailed explanation.
In addition to adding reporting of the oxidation factor used, we
are also proposing clarification of the reporting requirements for
CH4 generation adjusted for oxidation for industrial waste
landfills with gas collection systems. Under 40 CFR 98.463(b)(1), we
require all industrial waste landfills reporting under Subpart TT to
calculate their CH4 generation, adjusted for oxidation, from
the modeled CH4 (GCH4 from Equation TT-1) using
Equation TT-6. For landfills without gas collection systems, we then
require the reporting of the result of this equation in 40 CFR
98.466(g)(1), which is also the annual CH4 emissions from
these landfills. For landfills with gas collection systems, we require
the reporting of the requirements in paragraphs 40 CFR 98.466(a)
through (f) in addition to 40 CFR 98.346(i). In the cross-reference to
40 CFR 98.346(i) we inadvertently required facilities to report, under
40 CFR 98.346(i)(8), their CH4 generation adjusted for
oxidation based using Equation HH-5 rather than Equation TT-6. While
these equations appear identical, the modeled CH4 generation
term is defined as the result of the Equation HH-1 in Equation HH-5
rather than the result of Equation TT-1 as in Equation TT-6. We never
intended to have industrial waste landfills that have gas collection
systems to calculate their modeled CH4 generation using
Equation HH-1 (with its default DOC and k parameter values associated
with MSW) rather than using Equation TT-1 (with default DOC and k
parameter values for industrial wastes). To provide improved clarity in
the reporting of CH4 generation adjusted for oxidation for
industrial waste landfills with gas collection systems, we are
therefore proposing to amend 40 CFR 98.466(h) to read ``For landfills
with gas collection systems, in addition to the reporting requirements
in paragraphs (a) through (f) of this section, provide: (1) The annual
methane generation, adjusted for oxidation, calculated using Equation
TT-6 of this subpart, reported in metric tons CH4; (2) The
oxidation factor used in Equation TT-6 of this subpart; and (3) All
information required under 40 CFR 98.346(i)(1) through (7) and 40 CFR
98.346(i)(9) through (12).'' \45\
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\45\ The EPA has proposed a data category and confidentiality
determination for the revised data elements of 40 CFR 98.466(h). See
the Confidentiality Determinations Memorandum (Docket Id. No. EPA-
HQ-OAR-2012-0934).
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Finally, we are proposing changes to Table TT-1 of subpart TT of
Part 98. During implementation of Part 98, a question arose regarding
the default value for pulp and paper wastes questioning whether the
2006 IPCC Guidelines recommended value of 0.09 instead should be used
for wastewater sludges. We reviewed the 2006 IPCC Guidelines as well as
laboratory test data results for pulp and paper wastewater sludges
provided by NCASI (see memorandum ``Calculations documenting the
greenhouse gas emissions from the pulp and paper industry'' from R.A.
Miner, NCASI, to B. Nicholson, RTI International, dated May 21,2008, in
Docket ID No. EPA-HQ-OAR-2012-0934). Based on the available data, we
agree that the industrial sludge default value for DOC of 0.09 appears
to provide a more accurate estimate of the DOC than the generic
industry defaults currently provided in the rule. Consequently, we are
proposing to revise Table TT-1 to include the DOC default value of 0.09
for ``Industrial Sludge.''
We are also proposing to revise the titles of the industry specific
categories in Table TT-1 to note that these industry specific
parameters apply to the industry waste streams ``(other than sludge).''
The addition of the new default DOC value for industrial sludge in
Table TT-1 also requires the addition of corresponding k-values. The
2006 IPCC Guidelines do not provide default k-values for industrial
wastes (sludge or otherwise); the IPCC Waste Model (a spreadsheet tool
to help implement the 2006 IPCC Guidelines for landfills) uses the same
k-values for industrial wastes as for bulk MSW. While it is anticipated
that sludge generated by different industries will have different decay
rates (and therefore different k-values), we have very little data by
which to determine industry-specific k-values for the new default
``Industrial Sludge'' waste type. The k-values for ``Other Industrial
Solid Waste'' waste type in Table TT-1 were selected based on country-
specific default k-values for bulk MSW in U.S. landfills following the
general default assumptions used in the IPCC Waste Model. These same k-
values (0.02, 0.04, and 0.06 for dry, moderate, and wet climates,
respectively) are being proposed as the default k-values for the new
``Industrial Sludge'' waste type for the same reasons (i.e., based on
country-specific default k-values for bulk MSW in U.S. landfill
following general default assumptions used in the IPCC Waste model). We
specifically request comment from reporters on these proposed k-values
and we further request that the commenters provide any applicable data
to support comments.
Z. Subpart UU--Injection of Carbon Dioxide
We are proposing technical amendments to 40 CFR part 98, subpart UU
(Injection of Carbon Dioxide) to clarify provisions and improve
verification of reported GHG data. The more substantive corrections,
clarifying, and other amendments to subpart UU are discussed in this
section. Additional minor corrections are discussed in the Table of
Revisions for this rulemaking (see Docket ID No. EPA-HQ-OAR-2012-0934).
The EPA is proposing to add a requirement to subpart UU for a
facility to report the purpose of CO2 injection (i.e.,
Research and Development (R&D) project exemption from subpart RR,
enhanced oil or gas recovery, acid gas disposal, or some other reason)
to aid
[[Page 19832]]
the agency in verification of data reported under subpart UU and to
allow the EPA to understand the nature of the CO2 injection
operations for the purposes of data analysis to inform policy
development.\46\ We do not anticipate that this change would
significantly increase burden for reporters.
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\46\ The EPA has proposed category assignments and
confidentiality determinations for new and revised data elements in
the Confidentiality Determinations Memorandum (Docket Id. No. EPA-
HQ-OAR-2012-0934).
---------------------------------------------------------------------------
We are also proposing to add a requirement for facilities to report
the standard or method used to calculate the parameters for
CO2 received in containers. This new reporting element will
be used for verification purposes.\47\ The proposed data element does
not require additional data collection or monitoring from reporters,
and as it is not a significant change, will not add burden to reporting
entities.
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\47\ Id.
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AA. Other Technical Corrections
In addition to the corrections, clarifying, and other amendments
proposed in Sections II.A through II.Z of this preamble, we are
proposing minor corrections to subparts E, G, O, S, V, and II of Part
98. The proposed changes to these subparts are provided in the Table of
Revisions for this rulemaking, available in Docket ID No. EPA-HQ-OAR-
2012-0934, and include clarifying requirements to better reflect the
EPA's intent, corrections to calculation terms or cross-references that
do not revise the output of calculations, harmonizing changes within a
subpart (such as changes to terminology), simple typo or error
corrections, and removal of redundant text.
III. Schedule for the Proposed Amendments
A. When would the proposed amendments become effective?
The EPA is planning to address the comments on these proposed
changes and publish any final amendments before the end of 2013. This
section describes when the proposed amendments would become effective
for existing reporters and new facilities that could be required to
report as a result of the proposed amendments to Table A-1 of subpart
A. This section also discusses proposed amendments to subpart A for the
use of best available monitoring methods (BAMM) by new reporters and
for options considered for revising emissions estimates due to the
change in GWPs for 2010, 2011, and 2012 reports previously submitted by
existing reporters.
1. Existing Reporters
We have determined that it would be feasible for existing reporters
to implement the proposed changes for the 2013 reporting year because
these changes are consistent with the data collection and calculation
methodologies in the current rule. The proposed revisions primarily
provide additional clarifications or flexibility regarding the existing
regulatory requirements, would not add new monitoring requirements, and
would not substantially affect the information that must be collected.
Where calculation equations are proposed to be modified, the changes
clarify equation terms or simplify the calculations and do not require
any additional data monitoring. The owners or operators are not
required to actually submit reporting year 2013 reports until March 31,
2014, which is several months after we expect a final rule based on
this proposal to be finalized, thus providing an opportunity for
reporters to adjust to any finalized amendments.
We are proposing that existing GHGRP reporters begin using the
updated GWPs in Tables A-1 for their reporting year 2013 annual
reports, which must be submitted by March 31, 2014. In keeping with the
March 15, 2012 UNFCCC decision, the Inventory submitted to the UNFCCC
in 2015 must use AR4 GWP values (see Section II.A.1.a of this
preamble). Development of the 2015 Inventory will rely in part on data
from the GHGRP reports submitted in 2014 to supplement the top-down
national estimate. Existing GHGRP reporters would also begin
calculating facility GHG emissions or supply using the proposed GWPs
for the additional F-GHGs discussed in Section II.A.1.c of this
preamble for their reporting year 2013 annual reports. The proposed
amendments would pose a minimal burden to existing reporters. Part 98
already requires that existing reporters report these F-GHGs in metric
tons of chemical emitted or supplied.\48\ Therefore, facilities are
already collecting information on emissions and supply for these
substances, and in some cases have provided GWP estimates for these
compounds. Furthermore, the proposed amendments only provide a factor
to convert emissions to CO2e, and do not change the type of
data collected. The EPA also does not anticipate that the proposed GWPs
would require any existing reporters to report under new subparts; such
a reporter, if one exists, would not be required to report for any past
years under any subparts for which the reporter's emissions newly
exceed a reporting threshold. Therefore, we anticipate that there is no
significant burden for existing reporters to use the proposed GWP
values for reporting year 2013.
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\48\ The sole exception is Subpart L, under which the
requirement to report these F-GHGs on a mass basis is deferred for
reporting years 2011 and 2012 (and 2013, under this proposal), but
reporters are required to keep records of the data and calculations
used to estimate aggregate emissions in CO2e for the
entire facility (77 FR 51477, August 24, 2012).
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In some cases we are proposing revisions to reporting requirements
to clarify requirements or to make harmonizing changes within a subpart
or between subparts under Part 98. The EPA anticipates that the
proposed reporting requirements are either already being collected by
reporters or would be readily available to reporters. For example, we
are revising reporting requirements to 40 CFR part 98, subpart A to
include additional data for identification purposes, such as the
latitude and longitude for facilities without a physical address, or
the ORIS code for power generation units (an identifier assigned by the
Energy Information Administration). In the case of 40 CFR part 98,
subpart K (Ferroalloy Production), we are proposing to add a
requirement to report the annual process CH4 emissions (in
metric tons) from each EAF where the carbon mass balance procedure is
used to measure emissions. This reporting requirement is an aggregate
of data that is currently being monitored from each EAF. Similarly,
under 40 CFR part 98, subpart Y (Petroleum Refineries), we are
clarifying the reporting requirements by adding a provision to specify
that when the process vent calculation method using Equation Y-19 is
used to calculate emissions for asphalt blowing operations or delayed
coking units, the facility must report the information required under
40 CFR 98.256(l)(5), which are the reporting requirements for process
vents. This is a clarification of the reporting parameters required
when an alternate calculation methodology is used. In the case of 40
CFR part 98, subpart Z (Phosphoric Acid Production), we are proposing
to require reporting of the number of times missing data procedures
were used to estimate CO2 content. Because the proposed
changes to these subparts would not require new monitoring or data
collection but could be determined from existing monitoring and
recordkeeping, the EPA has determined that it would be feasible to
include these
[[Page 19833]]
new reporting requirements in 2013 reports.
In the case of subpart N (Glass Production), we are proposing to
revise the monitoring methods used to measure carbonate-based mineral
mass-fractions to allow for more accurate measurement methods and to
add flexibility for reporters. The proposed amendments would specify
that reporters determining the carbonate-based mineral mass fraction
must use sampling methods that specify X-ray fluorescence, instead of
the current methods that use inductively coupled plasma or atomic
absorption. For measurements made in the emission reporting year 2013
or prior years, reporters would continue to have the option to use the
current monitoring methods in Part 98. This change would allow
reporters flexibility in choosing a sampling method (since multiple X-
ray fluorescence methods are available) while ensuring that more
accurate available measurement methods are applied in future reporting
years. These facilities would have the option, but not be required, to
use the newly proposed option for the reporting year 2013 reports
submitted to the EPA in 2014.
In some cases, we are proposing to require reporting of additional
data elements to improve verification of the reported GHGs emitted or
supplied. For example, for 40 CFR part 98, subpart FF (Underground Coal
Mines), we are proposing to substantiate the data collected for
identification of each well and shaft by adding a requirement to report
the start date and close date of each well or shaft and the number of
days the well or shaft was in operation during the reporting year. In
the case of subpart UU (Injection of Carbon Dioxide), we are proposing
to require reporting of the purpose of CO2 injection,
whether the facility received a Research and Development project
exemption from reporting under subpart RR of Part 98 for the reporting
year, and the start and end dates of the exemption, if applicable. The
proposed changes would not significantly burden reporters or affect
reporting year 2013 reports because this information is expected to be
readily available to reporters as part of their standard recordkeeping
and would not require additional monitoring or recordkeeping for 2013
reports.
In the case of 40 CFR part 98, subpart NN (Suppliers of Natural Gas
and Natural Gas Liquids), we are proposing a change to Equation NN-5 to
better reflect actual operating conditions. We are proposing to replace
Equation NN-5 with two equations, NN-5a and NN-5b, with harmonizing
changes to Equation NN-6. The proposed equations would allow for the
use of different emission factors for natural gas that is stored and
for natural gas that bypasses the city gate, such as natural gas
received from local production. We are proposing harmonizing changes to
the reporting requirements to specify the quantity of gas that bypasses
the city gate and the net quantity of gas that is placed into or
withdrawn from on-system storage during the reporting year. The
proposed changes do not substantially revise the calculation
methodology, but are changes that would provide more accurate GHG
estimates in situations where the LDC receives several different
streams of natural gas with different characteristics. Furthermore, the
proposed changes do not revise the information that must be collected
for recordkeeping or reporting. Therefore, we have concluded that under
the proposed amendments, existing sources could use the same
information that they have been collecting under the current Part 98
and readily available information for each subpart to determine
applicability and to calculate and report GHG emissions for reporting
year 2013.
The EPA specifically seeks comment on the conclusion that it is
appropriate to implement these amendments and incorporate the
requirements in the data reported to the EPA by March 31, 2014.
Further, we specifically seek comment on whether there are specific
subparts or amendments for which this timeline may not be feasible or
appropriate due to the nature of the proposed changes or the way in
which data have been collected thus far. We request that commenters
provide specific examples of how and why the proposed implementation
schedule would not be feasible.
2. New Reporters
As a result of the proposed amendments to the GWPs in Table A-1 of
subpart A, some facilities that were never previously required to
report under Part 98 may be required to report (see Section V.A of this
preamble). Given that a final rule based on this proposed rule would
not be finalized until the second half of 2013, we have determined that
it would not be feasible for these new facilities to acquire, install,
and calibrate monitoring equipment, collect data, and implement these
changes for reporting year 2013. Therefore, we are proposing that new
reporters who would be required to report under Part 98 as a result of
the proposed changes to Table A-1 would begin collecting data on
January 1, 2014 for the 2014 reporting year. New reporters would be
required to submit their first reports, covering the 2014 reporting
year, on March 31, 2015. The intended schedule (including publication
of any final rule by the end of 2013) would allow time for new
reporters to acquire, install, and calibrate monitoring equipment for
the 2014 reporting year.
We are also proposing to add provision 40 CFR 98.3(l) to subpart A
to allow new reporters who would be required to report as a result of
the proposed new or revised GWPs to have the option of using BAMM from
January 1, 2014 to March 31, 2014 for any parameter that cannot
reasonably be measured according to the monitoring and QA/QC
requirements of a relevant subpart. The EPA understands that because
any final rule based on this proposal likely would not be promulgated
until the fall of 2013, facilities that do not already have the
monitoring systems required by the rule in place might not have time to
install and begin operating them by January 1, 2014. Therefore, we are
proposing that reporters be allowed to use BAMM during the January 1,
2014 to March 31, 2014 time period without formal request to the EPA.
Reporters would also have the opportunity to request an extension for
the use of BAMM beyond March 31, 2014; those owners or operators must
submit a request to the Administrator by 60 days after the effective
date of the final rule. The EPA anticipates granting approval for BAMM
no later than December 31, 2014. The EPA has concluded that the time
period allowed under this schedule (including the provision for
facility-specific requests) is reasonable and will allow facilities
that do not currently have the required monitoring systems sufficient
time to begin implementing the monitoring methods required by the rule.
The proposed schedule would allow approximately six months to prepare
for data collection, which is consistent with existing BAMM provisions
provided under subpart A of Part 98. By allowing the additional time,
many facilities may also be able to install any necessary equipment
during other planned (or unplanned) process unit downtime, thus
avoiding process interruptions.
B. Options Considered for Revision and Republication of Emissions
Estimates for Prior Year Reports
The EPA is proposing to independently recalculate revised
CO2e emissions from the 2010, 2011, and 2012 reporting year
emissions or supply for each facility using the revised GWPs in Table
A-1. We considered two
[[Page 19834]]
options for revising the CO2e emission estimates from annual
reports for reporting years 2010, 2011, and 2012 using the proposed GWP
values in Table A-1. Revision of CO2e emission estimates in
reports for years 2010, 2011, and 2012, either by reporters or by the
EPA, would allow for the comparison of emission data submitted for
those reporting years with data submitted in 2013 and future reporting
years and ensure that published annual GHG reports are based on a
common metric. This would allow the EPA and the public to more
efficiently analyze changes in GHG emissions and industry trends in a
time series.
Option 1: Under this option, which is not preferred by EPA,
reporters who have submitted annual reports for the reporting years
2010, 2011, and 2012 would be required to resubmit their prior year
reports using the revised GWPs. Under this option, reporters would use
the built-in calculation methods in the EPA's Electronic Greenhouse Gas
Reporting Tool (e-GGRT) to convert reported quantities of GHGs to
CO2e per the requirements of 40 CFR 98.2(b)(4).\49\ To
adjust prior year reports, the system would recalculate facility GHG
emissions using the revised GWP values in Table A-1, yielding a new
CO2e for each GHG in the annual report.\50\ Reporters would
then recertify and sign the reports as required by 40 CFR 98.4(e) and
resubmit the reports through e-GGRT.
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\49\ For reporters using the e-GGRT web forms, the system
currently automatically applies the GWP values in Table A-1 of
subpart A to reported facility emissions (metric tons) to convert
emissions to CO2e, according to the requirements of
Subpart A (General Provisions).
\50\ For reporters using the XML schema to submit annual GHG
reports, reporters would apply the revised GWP values in Table A-1
of subpart A in their submitted XML reports to recalculate emission
or supply estimates, following the XML reporting instructions
provided through e-GGRT. For these reporters, the system would
validate the CO2e estimates provided in the XML report
against automatically calculated e-GGRT values, using the revised
GWPs in Table A-1.
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The proposed revised GWP values in Table A-1 will likely result in
changes to the CO2e estimates of GHGs emitted or supplied in
previous reporting years. In most cases, this will result in higher
estimates of CO2e emitted or supplied, rather than lower
estimates. Reporters may desire to review and certify the revised
emission estimates prior to data publication by the EPA. So we have
included this option for comment. This option would give reporters
greater control over the republication of their data, and emission or
supply totals would be certified by reporters. However, this option
would present an additional burden on reporters. The EPA calculates
that existing reporters would incur a total one-time cost of $3.5
million for resubmittal and recertification of 2010, 2011, and 2012
reports. This represents a one-time cost for 2010 reporters of $347 per
facility for the resubmittal of 2010, 2011, and 2012 reports, and a
cost of $231 per facility for 2011 reporters for the resubmittal of
2011 and 2012 reports. In addition, the EPA recognizes that some
facilities may no longer be required to report under Part 98 or may
have ceased operations. Obtaining revised emissions estimates from
these facilities could be difficult; therefore, the EPA may not be able
to revise the complete data set for prior reporting years. For these
reasons, the EPA does not prefer this option.
Option 2: The EPA would independently recalculate revised
CO2e emissions from the 2010, 2011, and 2012 reporting year
emissions or supply for each facility using the revised GWPs in Table
A-1. Under this scenario, through e-GGRT, each reporter would be able
to see the EPA's revision of its emission or supply totals in
previously submitted 2010, 2011, and 2012 reports before that
information is publically available. However, although the reporter
would be able to view the estimate, the reporter would not be able to
comment on or change the revised estimate. The EPA would publish the
revised estimates with a caveat explaining how the estimates were
obtained and explaining that the emission values are not those
submitted and certified by reporters. While the calculation is very
straightforward for most reporters, because subpart L reporters have
not reported the specific compounds that make up their emissions, there
could be some uncertainty associated with the revisions to subpart L
emission data if option 2 is selected.
This option would allow the EPA to publish revised emission and
supply totals without increasing burden on reporters. This option would
remove the need for reporters to resubmit and recertify revised
reports. However, Option 2 would not give reporters the opportunity to
provide feedback on their individual revised emissions or supply
totals, or allow them to certify the amended totals at any point before
or after republication. As reporters would be unable to submit revised
emission estimates or comment on the estimation methods used to
calculate the updated CO2e totals, they would have less
control over the revised data. Although Option 1 would give reporters
more input in the revised emission or supply totals provided to the
public, we do not anticipate that the benefits of requiring data
resubmission and certification would justify the increased burden on
reporters discussed above. Option 2 would not present any additional
burden for reporters. Option 2 would allow the EPA to publish revised
emission and supply totals for all facilities which submitted a report
for 2010, 2011, and 2012, including facilities which have ceased
operations or which are no longer required to report. This approach
would allow the EPA to reconstruct the complete data set for prior year
reports for comparison to data reported for 2013 and future years. In
light of these considerations, the EPA prefers Option 2. The EPA seeks
comment on the two options. Specifically, we request comment on the
need for review and certification of revised emission estimates by
reporters and whether revised calculations prepared by the EPA, as
proposed in Option 2, would be sufficient for publication.
IV. Confidentiality Determinations
A. Overview and Background
In this notice we are proposing confidentiality determinations for
the new or substantially revised reporting data elements (i.e., the
data required to be reported would change under the proposed revision)
in the proposed subpart rule amendments, except for inputs to
equations.\51\ For information on the history of confidentiality
determinations for Part 98 data elements, see the following notices:
---------------------------------------------------------------------------
\51\ As discussed later in the preamble, we propose to assign
certain new or substantially revised data elements to the ``inputs
to emission equations'' category but do not propose confidentiality
determinations for these data elements.
---------------------------------------------------------------------------
75 FR 39094, July 7, 2010; hereafter referred to as the
``July 7, 2010 CBI proposal.'' Describes the data categories EPA
developed for the Part 98 data elements.
76 FR 30782, May 26, 2011; hereafter referred to as the
``2011 Final CBI Rule.'' Assigned data elements to data categories and
published the final CBI determinations for the data elements in 34 Part
98 subparts, except for those data elements that were assigned to the
``Inputs to Emission Equations'' data category.
77 FR 48072, August 13, 2012, hereafter referred to as
``2012 Final CBI Determinations Rule.'' Finalized confidentiality
determinations for data elements to be reported under nine subparts I,
W, DD, QQ, RR, SS, UU; except for those data elements that are inputs
to emission equations, and finalized confidentiality determinations for
new data elements added to subparts
[[Page 19835]]
II and TT in the November 29, 2011 Technical Corrections Notice (76 FR
73886).
77 FR 51477, August 24, 2012; hereafter referred to as the
``2012 Technical Corrections and Subpart L Confidentiality
Determinations.'' Finalized confidentiality determinations for new data
elements added to subpart L.
In this action, the EPA is proposing confidentiality determinations
for new or substantially revised data elements. The new and
substantially revised data elements result from the proposed
corrections, clarifying, and other amendments that are described in
Section II of this preamble. These proposed confidentiality
determinations would be finalized based on public comment. The EPA
currently plans to finalize these determinations at the same time the
proposed rule amendments described in Sections II and III of this
preamble are finalized. We are not proposing new confidentially
determinations for data reporting elements that may be minimally
revised for clarification or to correct insignificant errors, where the
change does not require an additional or different data element to be
reported. The final confidentiality determinations the EPA has
previously made for these data elements are unaffected by this proposed
amendment and continue to apply.
B. Approach to Proposed Confidentiality Determinations for New or
Substantially Revised Data Elements
In this action, we are proposing to add or substantially revise
data reporting requirements in subparts A, H, K, X, Y, Z, AA, FF, HH,
NN, QQ, RR, TT, and UU. We propose to assign each of the newly proposed
or substantially revised data elements in these subparts to one of the
direct emitter or supplier data categories created in the 2011 Final
CBI Rule (76 FR 30782, May 26, 2011). In the 2011 Final CBI Rule, the
EPA made categorical confidentiality determinations for data elements
assigned to eight direct emitter data categories and eight supplier
data categories. For two direct emitter data categories, ``Unit/Process
`Static' Characteristics that Are Not Inputs to Emission Equations''
and ``Unit/Process Operating Characteristics that Are Not Inputs to
Emission Equations,'' the EPA determined in the 2011 Final CBI Rule
that the data elements assigned to those categories are not emission
data but did not make categorical CBI determinations. Rather, the EPA
made CBI determinations for individual data elements assigned to these
two data categories. Similarly, for three supplier data categories,
``GHGs Reported,'' ``Production/Throughput Quantities and
Composition,'' and ``Unit/Process Operating Characteristics,'' the EPA
determined in the 2011 Final CBI Rule that the data elements assigned
to those categories are not emission data but did not make categorical
CBI determinations; instead the EPA made CBI determinations for
individual data elements assigned to these two data categories. In
subsequent amendments to Part 98,\52\ the EPA assigned each new or
substantially revised data element to an appropriate data category
created in the 2011 Final CBI Rule and applied the categorical
confidentiality determination if one was established in the 2011 Final
CBI Rule. If a data element was assigned to one of the two direct
emitter or three supplier data categories identified above that do not
have categorical determinations, the EPA made individual CBI
determinations. With respect to data elements for which the revisions
did not change the type of data to be reported, their categorical
assignments and confidentiality determinations (whether categorical or
individual determinations) are not affected by this proposed amendment
and therefore remain unchanged. The EPA did not make final
confidentiality determinations for data elements assigned to the inputs
to emission equations category either in the 2011 Final CBI rule or any
subsequent Part 98 rulemaking. We are following the same approach in
this proposed rule. Specifically, we are proposing to assign new or
substantially revised data elements in the proposed amendments to the
appropriate direct emitter or supplier data category.\53\ For new or
substantially revised data elements being assigned to categories with
categorical confidentiality determinations, we propose to apply the
categorical determinations made in the 2011 Final CBI Rule to the
assigned data elements. For new or substantially revised reporting
elements assigned to the ``Unit/Process `Static' Characteristics that
Are Not Inputs to Emission Equations'' and the ``Unit/Process Operating
Characteristics that Are Not Inputs to Emission Equations'' direct
emitter data categories or the ``Unit/Process Operating
Characteristics'' supplier data categories, consistent with our
approach toward data elements previously assigned to these data
categories, we propose that these data elements are not emission data,
and are making individual CBI determinations for the data elements in
these categories.
---------------------------------------------------------------------------
\52\ See, e.g., 77 FR 48072 (August 13, 2012) and 77 FR 51477
(August 24, 2012).
\53\ Proposed determination is not needed for two data elements
proposed for subpart Y (40 CFR 98.256(j)(10) and 40 CFR
98.256(k)(6)), because they refer to an existing data element (40
CFR 98.256(l)(5)) for which a CBI determination has already been
finalized.
---------------------------------------------------------------------------
Please see the memorandum titled ``Proposed data category
assignments and confidentiality determinations for new and
substantially revised data elements in the proposed `2013 Revisions to
the Greenhouse Gas Reporting Rule and Confidentiality Determinations
for New or Substantially Revised Data Elements' '' (``Confidentiality
Determinations Memorandum'') in Docket EPA-HQ-OAR-2012-0934 for a list
of the proposed new or substantially revised data elements, their
proposed category assignments, and their proposed confidentiality
determinations (whether categorical or individual) except for those
assigned to the inputs to equations category. Section IV.C of this
preamble discusses the proposed CBI determinations and supporting
rationale for individual data elements.
C. Proposed Confidentiality Determinations for Individual Data Elements
in Two Direct Emitter Data Categories and Two Supplier Data Categories
The EPA is proposing individual CBI determinations for 16 data
elements assigned to the ``Unit/Process `Static' Characteristics that
Are Not Inputs to Emission Equations'', ``Unit/Process Operating
Characteristics that Are Not Inputs to Emission Equations'' direct
emitter data categories and the ``Production/Throughput Quantities and
Composition'' and ``Unit/Process Operating Characteristics'' supplier
data categories. (There are no new data elements proposed to be
assigned to the ``GHGs Reported'' supplier data category.) These data
elements consist of three new data elements in the direct emitter
subpart FF and eight in the supplier subpart UU. We are also proposing
individual CBI determinations for five substantially revised data
elements in the subparts Z, NN, TT, and QQ. Table 9 of this preamble
provides the category assignment and proposed rationale for the
proposed determinations.
[[Page 19836]]
Table 9--Data Elements Proposed To Be Assigned to Data Categories Without Categorical Determinations and
Proposed CBI Determinations (Subparts Z, NN, FF, QQ, TT, and UU)
----------------------------------------------------------------------------------------------------------------
New or revised data Rationale for the proposed
Citation element Data element CBI determination
----------------------------------------------------------------------------------------------------------------
Data Elements Proposed To Be Assigned to the ``Unit/process Static Characteristics That Are Not Inputs to
Emission Equations'' Direct Emitter Data Category
----------------------------------------------------------------------------------------------------------------
98.266(b)...................... Revised............... Annual phosphoric acid We are not proposing a
production capacity. determination for this data
element at this time. This
data element is being
revised from ``permitted
production capacity'' to
``production capacity''. As
discussed in the 2011 Final
CBI Rule (76 FR 30782), the
EPA reviewed available
capacity information in the
``Unit/process Static
Characteristics that Are Not
Inputs to Emission
Equations'' data category
and determined that these
data elements may not be
publically available for all
facilities and may be
competitively sensitive.
Revising the current data
element to ``production
capacity'' would require
reporting of actual
production capacity in lieu
of permitted production
capacity. Although this
information in some cases is
publicly available (e.g.,
Title V permits, NEI), this
data may still be
competitively sensitive for
other facilities. No
determination is being
proposed at this time; case-
by-case determinations will
be made when necessary.
----------------------------------------------------------------------------------------------------------------
Data Elements Proposed To Be Assigned to the ``Unit/process Operating Characteristics That Are Not Inputs to
Emission Equations'' Direct Emitter Data Category
----------------------------------------------------------------------------------------------------------------
98.326(r)(2)................... New................... Start date of each well We are proposing that these
and shaft. data elements are not
emission data and not CBI.
These proposed data elements
would provide additional
identification and
descriptive information for
each well or shaft.
98.326(r)(2)................... New................... Close date of each well
and shaft..
98.326(r)(3)................... New................... Number of days each well These data elements reveal
or shaft was in general information about
operation during the the operating
reporting year. characteristics of the
reporting facility and would
be assigned to the ``Unit/
process Operating
Characteristics that Are Not
Inputs to Emission
Equations'' data category.
We are proposing that these
data elements not be
considered CBI because they
characterize the total
operation period of each
well or shaft. None of these
data elements reveal
information regarding the
production characteristics
or production rates of any
individual well or shaft.
Furthermore, these data
elements are generally
publicly available. For
example, facilities
currently report shaft
operating periods to the
Mine and Safety Health
Administration (MSHA).
Additionally, facilities are
often required to report
well operation periods to
state agencies for other
regulatory purposes.
Therefore, these data
elements are not anticipated
to be sensitive information
and public disclosure of
these data elements is not
likely to cause substantial
competitive harm to the
reporting facility.
98.466(b)(1)................... Revised............... The number of waste We are proposing that this
streams for which data element is not emission
Equation TT-1 is used. data and not CBI. This data
element is being revised to
include ``inert'' waste
streams. The addition of
``inerts'' to the reporting
requirement clarifies that
inert waste streams must be
reported in the total number
of waste streams used to
calculate modeled CH4
generation, which may change
the value reported. This
data element does not
disclose any information
about the design or
operating characteristics of
production processes,
historical production
volumes, or any other
production related
information about the
landfill that competitors
could use to discern
sensitive information.
Therefore we are proposing a
determination of ``not
emission data and not CBI''.
----------------------------------------------------------------------------------------------------------------
Data Elements Proposed To Be Assigned to the ``Production/Throughput Quantities and Composition'' Supplier Data
Category
----------------------------------------------------------------------------------------------------------------
98.406(b)(2)................... Revised............... LDCs: Annual volume of We are proposing that this
natural gas placed into data element is not CBI. The
storage. change to this data element
is proposed in order to
harmonize the reported data
with the change to the
equations in subpart NN. The
change clarifies that the
volume to be reported is the
volume referenced as Fuel1
in the Equation NN-5a. The
volume reported is not
expected to change as a
result of the proposed
revision. As discussed in
the 2011 Final CBI Rule, the
EPA does not consider LDC-
level production/throughput
data as CBI because many of
the same data elements are
already collected and
released annually by the
Energy Information
Administration (EIA).
Therefore, we are proposing
that the data element is not
CBI.
[[Page 19837]]
98.436(a)(6)(iii).............. Revised............... If the reporter does not We are proposing that these
know the identity and data elements are CBI. These
the mass of the F-GHGs data elements were
within the closed cell previously assigned to the
foam: For closed cell ``Production/Throughput
foams that are not Quantities and Composition''
imported inside of data category and assigned a
equipment, the density ``CBI'' determination in the
in CO2e of the F-GHGs 2012 Final CBI
in the foam. Determinations Rule. The
proposed change to these
data elements is a
correction to match the
reported data element to the
units required to be
reported. The change
proposed is a change from
``mass in CO2e'' to
``density in CO2e''. The
units specified for the data
element are kg CO2e/cubic
foot, and are unchanged in
this proposal. These data
elements reveal importer-
and exporter-level
production information
(density of the fluorinated
gas within the foam) and the
disclosure of these data
elements would likely cause
substantial harm to the
competitive positions of
businesses reporting these
data. Therefore, we are
proposing to assign these
elements to the ``Production/
Throughput Quantities and
Composition'' data category
and a determination that the
data element is CBI.
----------------------------------------------------------------------------------------------------------------
98.436(a)(6)(iii).............. Revised............... If the reporter does not
know the identity and
the mass of the F-GHGs
within the closed cell
foam: For closed cell
foams that are not
exported inside of
equipment, the density
in CO2e of the F-GHGs
in the foam.
----------------------------------------------------------------------------------------------------------------
Data Elements Proposed To Be Assigned to the ``Unit/Process Operating Characteristics'' Supplier Data Category
----------------------------------------------------------------------------------------------------------------
98.476(e)(1)................... New................... Whether the facility These data elements reveal
received a Research and general information about
Development project the operating
exemption from characteristics of the
reporting under 40 CFR reporting facility and are
part 98, subpart RR for proposed to the ``Unit/
the reporting year. Process Operating
Characteristics'' supplier
data category. We are
proposing that these data
elements are not CBI. These
proposed data elements are
based on the compliance
requirements for R&D
facilities under subpart RR
that are not considered
sensitive information by the
EPA. We are proposing that
these data elements are non-
CBI because they would not
reveal any information about
production quantities,
process, or specific R&D
projects that could cause
competitive harm, but only
provide information about
whether the facility
received an approved
exemption from other subpart-
specific requirements under
Part 98 and the duration of
the exemption.
98.476(e)(1)................... New................... If you received a
Research and
Development project
exemption from
reporting under 40 CFR
part 98, subpart RR for
the reporting year, the
start date of the
exemption.
98.476(e)(1)................... New................... If you received a
Research and
Development project
exemption from
reporting under 40 CFR
part 98, subpart RR for
the reporting year, the
end date of the
exemption.
98.476(e)(2)................... New................... Whether the facility The proposed data elements
includes a well or would reveal general
group of wells where a information about the
CO2 stream was injected operating characteristics of
into subsurface the reporting facility and
geologic formations to would be assigned to the
enhance the recovery of ``Unit/Process Operating
oil during the Characteristics'' supplier
reporting year. data category, which contain
similar data elements. We
are proposing that these
data elements are not CBI.
The proposed data elements
would provide additional
information on the purpose
of the CO2 injection on a
facility-wide basis. The
proposed data elements would
not reveal any specific
information about the
quantities of CO2 received
or injected at specific
wells or information about
the production that could
cause competitive
disadvantage. We are
proposing that these data
elements are not considered
CBI because they do not
reveal any detailed
information that is likely
to cause competitive harm if
publicly released.
[[Page 19838]]
98.476(e)(3)................... New................... Whether the facility
includes a well or
group of wells where a
CO2 stream was injected
into subsurface
geologic formations to
enhance the recovery of
natural gas during the
reporting year.
98.476(e)(4)................... New................... Whether the facility
includes a well or
group of wells where a
CO2 stream was injected
into subsurface
geologic formations for
acid gas disposal
during the reporting
year.
98.476(e)(5)................... New................... Whether the facility
includes a well or
group of wells where a
CO2 stream was injected
for a purpose other
than those listed in
(e)(1)through (4) of 40
CFR 98.476.
98.476(e)(5)................... New................... The purpose of the
injection, if you
injected CO2 for a
purpose of than those
listed in paragraph
(e)(1) through (4) of
40 CFR 98.476.
----------------------------------------------------------------------------------------------------------------
D. Proposed New Inputs to Emission Equations
As discussed in Section IV.C of this preamble, the EPA is proposing
category assignment for the new and substantially revised data
elements. As shown in the Confidentiality Determinations Memorandum
(see Docket Id. No. EPA-HQ-OAR-2012-0934), the EPA is proposing to
assign 13 new data elements to the ``inputs to emission equations
category'': Two in subpart FF, five in subpart HH, and six in subpart
TT. The EPA had previously deferred the reporting deadlines for inputs
to emissions equations until March 2013 for some data elements and
March 2015 for others to allow EPA sufficient time to conduct an ``in-
depth evaluation of the potential impact from the release of inputs to
equations'' (76 FR 53057 and 53060, August 25, 2011); (77 FR 48072,
August 13, 2012). We are not proposing to defer the reporting of these
13 data elements. The EPA has conducted an evaluation of these inputs
following the process outline in the memorandum ``Process for
Evaluating and Potentially Amending Part 98 Inputs to Emission
Equations'' (Docket ID EPA-HQ-OAR-2010-0929), which accompanied the
Final Deferral Rule (76 FR 53057). This evaluation is summarized in the
memorandum ``Summary of Evaluation of `Inputs to Emission Equations'
Data Elements Proposed to be Added with the 2013 Revisions to the
Greenhouse Gas Reporting Rule.'' (See Docket ID No. EPA-HQ-OAR-2012-
0934.) Because the EPA has completed the above mentioned evaluation for
these 13 data elements, EPA does not see a need to defer their
reporting. Accordingly, under this proposed amendment, these data
elements would be reported in 2014 along with the rest of the proposed
changes.
E. Request for Comments on Proposed Category Assignments and
Confidentiality Determinations
For the CBI component of this rulemaking, we are soliciting comment
on the following specific issues. First, we specifically seek comment
on the proposed data category assignment for each of the new or
substantially revised data elements in the proposed amendments to
subparts A, H, K, X, Y, Z, AA, FF, HH, NN, QQ, RR, TT, and UU.
If you believe that the EPA has improperly assigned certain new or
substantially revised data elements in these subparts to any of the
data categories established in the 2011 Final CBI Rule, please provide
specific comments identifying which of the new data elements may be
mis-assigned along with a detailed explanation of why you believe them
to be incorrectly assigned and in which data category you believe they
belong. In addition, if you believe that a data element should be
assigned to one of the five categories that do not have a categorical
confidentiality determination, please also provide specific comment
along with detailed rationale and supporting information on whether
such data element does or does not qualify as CBI.
We seek comment on the proposed confidentiality status of the new
or substantially revised data elements in the direct emitter data
categories ``Unit/Process `Operating' Characteristics that Are Not
Inputs to Emission Equations'' and ``Unit/Process `Static'
Characteristics that Are Not Inputs to Emission Equations'' and the
supplier data categories ``Production/Throughput Quantities and
Composition'' and ``Unit/Process Operating Characteristics.'' By
proposing confidentiality determinations prior to data reporting
through this proposal and rulemaking process, we provide potential
reporters an opportunity to submit comments, in particular comments
identifying data they consider sensitive and their rationales and
supporting documentation; this opportunity is the same opportunity that
is afforded to submitters of information in case-by-case
confidentiality determinations. In addition, it provides an opportunity
to rebut the Agency's proposed determinations prior to finalization. We
will evaluate the comments on our proposed determinations, including
claims of confidentiality and
[[Page 19839]]
information substantiating such claims, before finalizing the
confidentiality determinations. Please note that this will be
reporters' only opportunity to substantiate a confidentiality claim.
Upon finalizing the confidentiality determinations of the data elements
identified in this rule, the EPA will release or withhold these data in
accordance with 40 CFR 2.301, which contains special provisions
governing the treatment of Part 98 data for which confidentiality
determinations have been made through rulemaking.
When submitting comments regarding the confidentiality
determinations we are proposing in this action, please identify each
individual proposed new or revised data element you do or do not
consider to be CBI or emission data in your comments. Please explain
specifically how the public release of that particular data element
would or would not cause a competitive disadvantage to a facility.
Discuss how this data element may be different from or similar to data
that are already publicly available. Please submit information
identifying any publicly available sources of information containing
the specific data elements in question. Data that are already available
through other sources would likely be found not to qualify for CBI
protection. In your comments, please identify the manner and location
in which each specific data element you identify is publicly available,
including a citation. If the data are physically published, such as in
a book, industry trade publication, or federal agency publication,
provide the title, volume number (if applicable), author(s), publisher,
publication date, and International Standard Book Number (ISBN) or
other identifier. For data published on a Web site, provide the address
of the Web site and the date you last visited the Web site and identify
the Web site publisher and content author.
If your concern is that competitors could use a particular data
element to discern sensitive information, specifically describe the
pathway by which this could occur and explain how the discerned
information would negatively affect your competitive position. Describe
any unique process or aspect of your facility that would be revealed if
the particular proposed new or revised data element you consider
sensitive were made publicly available. If the data element you
identify would cause harm only when used in combination with other
publicly available data, then describe the other data, identify the
public source(s) of these data, and explain how the combination of data
could be used to cause competitive harm. Describe the measures
currently taken to keep the data confidential. Avoid conclusory and
unsubstantiated statements, or general assertions regarding potential
harm. Please be as specific as possible in your comments and include
all information necessary for the EPA to evaluate your comments.
V. Impacts of the Proposed Rule
This section of the preamble examines the costs and economic
impacts of the proposed rulemaking and the estimated economic impacts
of the rule on affected entities, including estimated impacts on small
entities.
A. Impacts of the Proposed Amendments to Global Warming Potentials
There are two primary reasons that Part 98 requires direct emitters
and suppliers of GHGs to use the GWP values in Table A-1 to subpart A
to calculate emissions (or supply) of GHGs in CO2e. The
first is to help determine whether the facility meets a
CO2e-based threshold and is required to report under Part
98. The second is to help calculate total facility emissions for
submittal in the annual report. A change to the GWP for a GHG will
change the calculated emissions (in CO2e) of that gas.
Therefore, the proposed amendments could affect both the number of
facilities required to report under Part 98 and the quantities of GHGs
reported.
For most GHGs whose GWPs we are proposing to amend, the proposed
AR4 GWP values are greater than the GWP values in the current Table A-
1. Therefore, the proposed amendments would likely result in higher
reported emissions of CO2e for facilities that emit these
gases. Although the proposed amendments would result in an increase in
reported emissions for many facilities that currently submit a report,
using the proposed GWPs would have no effect on the cost of monitoring
and recordkeeping and, therefore, no significant impact for reporters.
For the additional F-GHGs and associated GWPs we are proposing to
include in Table A-1, we do not anticipate significant impacts for
existing reporters. Per 40 CFR 98.3(c), facilities are required to
report annual CO2e emissions or supply, using Equation A-1,
for each GHG with a GWP in Table A-1. The proposed amendments to
subpart A would require Part 98 reporters to include emissions of the
new F-GHGs in Table A-1 (in CO2e) in their facility totals
in their annual reports. With the addition of the new F-GHGs, we expect
the quantities of CO2e reported to increase for reporters
that previously emitted, produced, imported, or exported the proposed
compounds and reported the annual quantities (metric tons) of these
gases in their 2010, 2011, or 2012 reports, but who were not required
to include the calculated CO2e emissions for these gases in
determining annual emissions of CO2e for their annual
report. Because these reporters are already required to meet
monitoring, recordkeeping, and reporting requirements for calculating
the quantity of the proposed F-GHGs in metric tons, additional costs to
report CO2e using the GWPs are expected to be insignificant.
Equation A-1 is also used to determine whether the rule applies to
direct emitters and suppliers in certain source categories where the
applicability of the GHG reporting rule is based on a threshold
quantity of GHGs that is either generated, emitted, imported, or
exported over a calendar year, expressed in CO2e. For some
direct emitters or suppliers in these source categories, calculating
CO2e using the proposed GWP values would result in higher
emissions or supply that might newly exceed the reporting threshold.
These facilities would then be required to begin reporting under Part
98 in 2014 (see Section III.A.2 of this preamble), with the associated
monitoring, recordkeeping, and reporting costs.
If finalized, the proposed amendments to Table A-1 would result in
a collective increase in annual reported emissions from all subparts of
more than 104 million metric tons CO2e (a 1.4 percent
increase in current emissions), which the EPA has concluded more
accurately reflects the estimated radiative forcing from the emissions
reported under Part 98. The increase would include 4.8 million metric
tons CO2e from an estimated 184 additional facilities that
would be newly required to report under Part 98 based on the new and
revised GWPs. The number of new reporters estimated, the estimated
increase in emissions or supply from existing reporters (reporters who
submitted 2010 and 2011 reports) and new reporters, and the estimated
total change in source category emissions or supply for each subpart
are summarized in Table 10 of this preamble.
[[Page 19840]]
Table 10--Summary of Estimated Impacts on Reported Emissions Due to Proposed Revisions to Table A-1 for Part 98
Subparts
----------------------------------------------------------------------------------------------------------------
Total reported Estimated
emissions or incremental Estimated change
supply for reported in reported source
Number of existing reporters Number of emissions or category emissions
Subpart existing prior to proposed estimated new supply for new or supply due to
reporters amendments (non- reporters reporters proposed
biogenic) (metric (metric tons amendments (metric
tons CO2e/year) CO2e/year) tons CO2e/year)
----------------------------------------------------------------------------------------------------------------
2010 Reporters
----------------------------------------------------------------------------------------------------------------
C....................... 4,211 619,572,472 0 0 112,339
D....................... 1,263 2,231,408,653 0 0 293,276
E....................... 2 4,397,310 0 0 (170,218)
F....................... 9 4,298,897 0 0 283,040
G....................... 22 13,596,985 0 0 0
H....................... 97 42,734,686 0 0 2,657
K....................... 10 2,240,907 0 0 1,743
N....................... 103 2,061,679 0 0 0
O....................... 5 6,351,797 0 0 1,682,955
P....................... 101 31,261,120 0 0 10
Q....................... 123 27,094,226 0 0 (21)
R....................... 12 588,209 0 0 0
S....................... 70 15,566,816 0 0 174
U....................... 19 122,663 0 0 0
V....................... 36 11,990,739 0 0 (464,158)
X....................... 63 9,445,122 0 0 11,973
Y....................... 145 55,751,060 0 0 100,695
Z....................... 13 1,080,913 0 0 0
AA...................... 110 7,562,923 0 0 50,408
BB...................... 1 122,466 0 0 2,141
CC...................... 4 1,221,863 0 0 0
EE...................... 7 1,447,634 0 0 0
GG...................... 6 730,209 0 0 0
HH...................... 1,202 107,000,000 57 1,560,000 2,787,153
MM...................... 155 2,493,881,410 0 0 0
NN...................... 476 909,000,000 0 0 0
OO...................... 167 254,554,000 3 75,000 44,060,000
----------------------------------------------------------------------------------------------------------------
2011 Reporters
----------------------------------------------------------------------------------------------------------------
I....................... 94 5,622,570 4 18,076 1,052,905
L....................... 14 10,600,000 0 0 1,060,000
T....................... 11 1,067,000 0 0 (37,213)
W....................... 2,786 337,000,000 99 2,572,881 41,136,821
DD...................... 141 10,320,000 0 0 (474,979)
FF...................... 114 33,823,404 0 0 6,442,553
II...................... 244 5,845,000 2 59,500 1,172,833
JJ \a\.................. 0 0 0 0 0
LL...................... 0 0 0 0 0
PP...................... 99 33,500,000 0 0 0
QQ...................... 108 21,907,182 0 0 1,915,000
RR...................... 10 7,162,885 0 0 0
SS...................... 10 814,128 0 0 (37,470)
TT...................... 200 13,700,000 19 520,000 3,129,524
UU...................... 92 48,735,442 0 0 0
---------------------------------------------------------------------------------------
Total............... 12,355 7,385,182,369 184 4,805,457 104,114,139
----------------------------------------------------------------------------------------------------------------
\a\ There are no reporters for subpart JJ of Part 98 because the EPA will not be implementing subpart JJ due to
a Congressional restriction prohibiting the expenditure of funds for this purpose.
Additional reporters would be expected to report under subparts I,
W, HH, II, OO, and TT due to an increase in the number of facilities
exceeding the CO2e threshold. The majority of these
additional reporters would be expected from subpart W, Petroleum and
Natural Gas Systems, and subpart HH, Municipal Solid Waste Landfills.
There are no expected additional reporters from the other 36 subparts.
We do not anticipate that the proposed revisions would reduce the
number of reporters that meet CO2e thresholds for any
subpart. The change in reported emissions or supply from each subpart
are summarized in Sections V.A.1 of this preamble. A detailed analysis
of the impacts for each subpart, including the number of additional
reporters expected, the quantities of annual GHGs reported, and the
compliance costs for expected additional reporters, is included in the
Impacts Analysis (see Docket ID No. EPA-HQ-OAR-2012-0934).
The total cost of compliance for the additional expected reporters
is $3.9 million for the first year and $1.2 million per year for
subsequent years. The annual costs for the additional reporters is an
approximate increase of 1.2 percent above the current reporters
[[Page 19841]]
cost of compliance with Part 98. The expected costs of the proposed
amendments and the associated methodology are summarized in Section
V.A.2 of this preamble.
1. How were the number of reporters and the change in annual emissions
or supply estimated?
The EPA evaluated the number of reporters affected by the proposed
amendments by examining the 2010 and 2011 reporters that are already
affected under Part 98. For the number of affected facilities, the EPA
examined available e-GGRT data from the 2010 reporting year and summary
data that were developed to support the current Part 98 to determine
the number of existing affected facilities. We then evaluated the
number of additional facilities that could be required to report under
each subpart by determining what additional facilities could exceed
Part 98 source category thresholds. Affected subparts that might have
additional reporters due to the proposed new or revised GWPs are those
that meet all of the following criteria: (1) The subpart has a
reporting threshold that is based on CO2e; (2) the subpart
requires reporting of emissions or supply of F-GHG, CH4, or
N2O, (other than combustion related emissions, which are a
small percentage of total combustion emissions); and (3) the EPA
estimates that there are some facilities in the source category that
did not previously exceed the threshold. The EPA analyzed the
applicability of these criteria to each subpart; the subparts that met
these three criteria and could have new reporters as a result of the
proposed changes to Table A-1 were subparts I, T, W, HH, II, OO, and
TT.
In order to determine the number of additional reporters expected
under these subparts, we used data from industry surveys and publicly
available data sources to compile a list of facilities that could be
affected in each subpart. Combined with source-specific data, we used
these facility lists to estimate the change in facility emissions or
supply using the proposed new and revised GWPs and to identify the
additional facilities in each subpart that could meet a
CO2e-based threshold. Following this review, the EPA
determined that there would likely be no new reporters from the
magnesium production source category (subpart T).
The EPA determined the estimated increases in reported emissions
for each subpart by examining the available data for 2010 and 2011
reporters. For existing facilities submitting an initial annual report
for reporting year 2010, the increase in calculated emissions from each
facility was estimated by adjusting the reported GHG mass emissions to
CO2e using the proposed AR4 GWP values. For existing
facilities required to submit an initial annual report for reporting
year 2011, we estimated CO2e emissions and supply using data
that was developed to support the original rule, such as the subpart-
specific technical support documents. We also estimated the increase in
emissions that would result from additional reporters in each subpart
expected to exceed the source category threshold. For those facilities,
the available source-specific emissions data for the expected new
reporters was calculated in terms of CO2e, and the estimated
emissions were included in the total source category emissions.
Additional information on the EPA's analysis of the estimated
number of reporters and the increase in reported CO2e for
each subpart is in the Impacts Analysis (see Docket ID No. EPA-HQ-OAR-
2012-0934).
2. How were the costs of this proposed rule estimated?
The compliance costs associated with the proposed amendments were
determined for those additional reporters who would be required to
submit an annual report under Part 98 if the proposed amendments to
Table A-1 were finalized. The total compliance costs for additional
reporters are estimated to be $3.9 million for the first year and $1.2
million for subsequent years (2011 dollars).
Costs for additional reporters are summarized in Table 11 of this
preamble, which presents the first-year and subsequent-year costs for
each source category.
Table 11--Cost Impacts of Proposed Amendments for Additional Reporters
----------------------------------------------------------------------------------------------------------------
Incremental
Incremental cost impact
Number of cost impact for additional
Subpart additional for additional reporters ($/
reporters due reporters ($/ yr for
to revised GWP yr for first subsequent
year) years)
----------------------------------------------------------------------------------------------------------------
I--Electronics Manufacturing.................................... 4 88,900 88,900
W--Petroleum & Natural Gas Systems.............................. 99 3,400,000 860,000
HH--Municipal Solid Waste Landfills............................. 57 309,700 137,500
II--Industrial Wastewater....................................... 2 10,300 10,300
OO--Industrial GHG Suppliers.................................... 3 10,500 10,500
TT--Industrial Waste Landfills.................................. 19 118,600 87,300
Total....................................................... 184 3,938,000 1,194,500
----------------------------------------------------------------------------------------------------------------
To estimate the cost impacts for additional reporters, the EPA used
the methodologies from the subpart-specific regulatory impacts analyses
from the original GHG reporting rule and updated the cost information
to 2011 dollars. In general, we determined total reporting costs for
each subpart by assigning model facility costs to individual affected
facilities in each industry sector. Labor costs were determined for
monitoring, recordkeeping, and reporting according to the rule
requirements. Capital costs for monitoring equipment were also
estimated for each model facility. The total cost for each subpart was
determined by multiplying the model facility cost by the number of
affected facilities.
For existing reporters that have submitted an annual report for
reporting year 2010 or 2011, there would be no significant cost impacts
resulting from the proposed amendments to Table A-1; using the proposed
GWPs would not affect the cost of monitoring and recordkeeping and
would not materially affect the cost for calculating emissions for
these facilities. See the Impacts Analysis (Docket ID No. EPA-HQ-OAR-
2012-0934) for more details.
[[Page 19842]]
B. Additional Impacts of the Proposed Technical Corrections and Other
Amendments
The proposed corrections also include clarifications to terms and
definitions for certain emission equations, simplifications to
calculation methods and data reporting requirements, or corrections for
consistency between provisions within a subpart or between subparts in
Part 98. In general, these clarifications and corrections do not
fundamentally affect the applicability, monitoring requirements, or
data collected and reported or increase the recordkeeping and reporting
burden associated with Part 98. Although we have added a few new
reporting provisions to select source categories, the data we are
proposing to collect is expected to be readily available to reporters;
in most cases, it would already have been recorded and would not
require additional monitoring or monitoring equipment for existing
reporters. Additionally, the proposed confidentiality determinations
for new or revised data elements would not affect whether and how data
are reported and therefore, would not impose any additional burden on
sources. See the EPA's full analysis of the additional impacts of the
corrections, clarifying, and other amendments in the Impacts Analysis
in Docket ID No. EPA-HQ-OAR-2012-0934).
VI. Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory Planning and Review and Executive
Order 13563: Improving Regulation and Regulatory Review
This action is not a ``significant regulatory action'' under the
terms of Executive Order 12866 (58 FR 51735, October 4, 1993) and is
therefore not subject to review under Executive Orders 12866 and 13563
(76 FR 3821, January 21, 2011). This action (1) proposes to clarify or
change specific provisions in the Greenhouse Gas Reporting Rule,
including amending Table A-1 of Subpart A to incorporate new and
revised GWPs, and (2) proposes confidentiality determinations for the
reporting of new or substantially revised (i.e., requiring additional
or different data to be reported) data elements contained in the
proposed amendments. The EPA prepared an analysis of the potential
compliance costs associated with the proposed amendments and amendments
to revise global warming potentials in subpart A. This analysis is
contained in the Impacts Analysis (see Docket ID No. EPA-HQ-OAR-2012-
0934). A copy of the analysis is available in the docket for this
action and the analysis is briefly summarized here. The total
compliance costs for additional reporters are $1,195,000 ($2011). The
highest costs are anticipated for 99 facilities affected by subpart W,
Petroleum and Natural Gas Systems, ($860,000), and 57 facilities
affected by subpart HH, Municipal Solid Waste Landfills ($137,500). New
facilities required to report under subparts I, II, OO, and TT would
incur a combined cost of $197,000. The proposed confidentiality
determinations for new and substantially revised data elements do not
increase the existing compliance costs. The compliance costs associated
with the proposed amendments are less than the significance threshold
of $100 million per year. The compliance costs for individual
facilities are not expected to impose a significant economic burden.
B. Paperwork Reduction Act
This action does not impose any new information collection burden.
This action proposes amended GWP values in subpart A and other
corrections and harmonizing revisions, and proposes confidentiality
determinations for the reporting of new or substantially revised (i.e.,
requiring additional or different data to be reported) data elements
contained in the proposed amendments. These proposed amendments and
confidentiality determinations do not make any substantive changes to
the reporting requirements in any of the subparts for which amendments
are being proposed. The proposed amendments to subpart A include
revision of GWPs in Table A-1 of subpart A. As discussed in Section V
of this preamble, the proposed amendments could affect the total number
of facilities reporting under Part 98 and increase the collective
annual emissions or supply reported. The EPA prepared an analysis of
the potential compliance costs associated with the proposed amendments
to Table A-1 in the Impacts Analysis (see Docket ID No. EPA-HQ-OAR-
2012-0934).
Other proposed amendments to subpart A include adding requirements
that provide reporters instruction regarding reporting of location,
ownership, and facility identification (i.e., reporting of ORIS codes).
The remaining proposed changes also include revising and adding
definitions. The proposed revisions are clarifications or require
reporting of information that facilities are expected to have readily
available (e.g., latitude and longitude of the facility, ORIS code for
each power generating unit), and are not expected to result in
significant burden for reporters.
The proposed amendments to the reporting requirements in the source
category-specific subparts generally do not change the nature of the
data reported and are not anticipated to result in significant burden
for reporters. For example, several of the proposed amendments are
clarifications or corrections to existing reporting requirements. For
example, for subpart H, the EPA is proposing to require reporting of
annual, facility-wide cement production instead of monthly, kiln-
specific cement production for facilities that use a CEMS to measure
CO2 emissions. Because facilities are already expected to
track facility-wide cement production for budgeting purposes, we do not
expect this revision to result in any additional burden for cement
production facilities. In some cases we are proposing to include
reporting requirements for data that are already collected by
reporters. For instance, for subpart RR, the EPA is proposing to add a
reporting requirement for facilities to report the standard or method
used to calculate the mass or volume of contents in containers that is
redelivered to another facility without being injected into the well.
The proposed data element does not require additional data collection
or monitoring from reporters, and is not a significant change.
The EPA is also proposing changes that would reduce the reporting
burden. For example, for subpart BB (Silicon Carbide Production), the
EPA is proposing to remove the requirement for facilities to report
CH4 emissions from silicon carbide process units or
furnaces. Additionally, the EPA is proposing to amend subpart BB such
that facilities would calculate and report CO2 emissions for
all process units and furnaces combined, instead of each process unit
or production furnace. We expect that both of these major changes will
reduce the reporting burden for facilities subject to subpart BB.
Additional changes to the reporting requirements in each subpart
are detailed in the Impacts Analysis (see Docket ID No. EPA-HQ-OAR-
2012-0934). The Office of Management and Budget (OMB) has previously
approved the information collection requirements for 40 CFR part 98
under the provisions of the Paperwork Reduction Act, 44 U.S.C. 3501 et
seq., and has assigned OMB control number 2060-0629, ICR 2300.10. The
OMB control numbers for EPA's regulations in 40 CFR are listed in 40
CFR part 9.
[[Page 19843]]
C. Regulatory Flexibility Act (RFA)
The Regulatory Flexibility Act (RFA) generally requires an agency
to prepare a regulatory flexibility analysis of any rule subject to
notice and comment rulemaking requirements under the Administrative
Procedure Act or any other statute unless the agency certifies that the
rule will not have a significant economic impact on a substantial
number of small entities. Small entities include small businesses,
small organizations, and small governmental jurisdictions.
For purposes of assessing the impacts of this proposed rule on
small entities, small entity is defined as: (1) A small business as
defined by the Small Business Administration's regulations at 13 CFR
121.201; (2) a small governmental jurisdiction that is a government of
a city, county, town, school district or special district with a
population of less than 50,000; and (3) a small organization that is
any not-for-profit enterprise which is independently owned and operated
and is not dominant in its field.
After considering the economic impacts of today's proposed rule on
small entities, I certify that this action will not have a significant
economic impact on a substantial number of small entities. The small
entities directly regulated by this proposed rule are small businesses.
We have determined that up to 37 small municipal solid waste landfills,
representing up to a .03% increase in regulated businesses in this
industry, will experience an impact of .02 to .60% of revenues; up to 3
suppliers of industrial GHGs, representing up to a .02% increase in
regulated businesses in this industry, will experience an impact of .02
to .14% of revenues; and that up to 19 industrial waste landfills
(primarily co-located with food processing facilities), representing up
to a .19% increase in regulated businesses in this industry, will
experience an impact of .01 to .48% of revenues.
Although this proposed rule will not have a significant economic
impact on a substantial number of small entities, the EPA nonetheless
has tried to reduce the impact of this rule on small entities. For
example, the EPA conducted several meetings with industry associations
to discuss regulatory options and the corresponding burden on industry,
such as recordkeeping and reporting. The EPA continues to conduct
significant outreach on the mandatory GHG reporting rule and maintains
an ``open door'' policy for stakeholders to help inform the EPA's
understanding of key issues for the industries.
We continue to be interested in the potential impacts of the
proposed rule amendments on small entities and welcome comments on
issues related to such impacts.
D. Unfunded Mandates Reform Act (UMRA)
The proposed rule amendments and confidentiality determinations do
not contain a federal mandate that may result in expenditures of $100
million or more for state, local, and tribal governments, in the
aggregate, or the private sector in any one year. Thus, the proposed
rule amendments and confidentiality determinations are not subject to
the requirements of section 202 and 205 of the UMRA.
This rule is also not subject to the requirements of section 203 of
UMRA because it contains no regulatory requirements that might
significantly or uniquely affect small governments. The proposed rule
amends specific provisions in subpart A, General Provisions, to reflect
global warming potentials that have been published by the IPCC and to
propose global warming potentials for certain fluorinated greenhouse
gases. Also in this action, the EPA is revising specific provisions to
provide clarity on what is to be reported. In some cases, the EPA has
increased flexibility in the selection of methods used for calculating
and monitoring GHGs. Therefore, this action is not subject to the
requirements of section 203 of the UMRA.
E. Executive Order 13132: Federalism
This action does not have federalism implications. It will not have
substantial direct effects on the States, on the relationship between
the national government and the States, or on the distribution of power
and responsibilities among the various levels of government, as
specified in Executive Order 13132.
These proposed amendments and confidentiality determinations apply
directly to facilities that directly emit greenhouses gases or that are
suppliers of greenhouse gases. They do not apply to governmental
entities unless the government entity owns a facility that directly
emits greenhouse gases above threshold levels (such as a landfill or
large combustion device), so relatively few government facilities would
be affected. Moreover, for government facilities that are subject to
the rule, the proposed revisions will not have a significant cost
impact. This regulation also does not limit the power of States or
localities to collect GHG data and/or regulate GHG emissions. Thus,
Executive Order 13132 does not apply to this action.
In the spirit of Executive Order 13132, and consistent with EPA
policy to promote communications between the EPA and state and local
governments, we specifically solicit comment on this proposed action
from state and local officials.
F. Executive Order 13175: Consultation and Coordination With Indian
Tribal Governments
This action does not have tribal implications, as specified in
Executive Order 13175 (65 FR 67249, November 9, 2000). The proposed
amendments and confidentiality determinations apply directly to
facilities that directly emit greenhouses gases or that are suppliers
of greenhouse gases. They would not have tribal implications unless the
tribal entity owns a facility that directly emits greenhouse gases
above threshold levels (such as a landfill or large combustion device).
Relatively few tribal facilities would be affected. Thus, Executive
Order 13175 does not apply to this action.
G. Executive Order 13045: Protection of Children from Environmental
Health Risks and Safety Risks
The EPA interprets Executive Order 13045 (62 FR 19885, April 23,
1997) as applying only to those regulatory actions that concern health
or safety risks, such that the analysis required under section 5-501 of
the Executive Order has the potential to influence the regulation. This
action is not subject to Executive Order 13045 because it does not
establish an environmental standard intended to mitigate health or
safety risks.
H. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use
This action is not subject to Executive Order 13211 (66 FR 28355
(May 22, 2001)), because it is not a significant regulatory action
under Executive Order 12866.
I. National Technology Transfer and Advancement Act
Section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (NTTAA), Public Law 104-113 (15 U.S.C. 272 note) directs
the EPA to use voluntary consensus standards in its regulatory
activities unless to do so would be inconsistent with applicable law or
otherwise impractical. Voluntary consensus standards are technical
standards (e.g., materials specifications, test methods, sampling
procedures, and
[[Page 19844]]
business practices) that are developed or adopted by voluntary
consensus standards bodies. NTTAA directs the EPA to provide Congress,
through OMB, explanations when the Agency decides not to use available
and applicable voluntary consensus standards.
This proposed rulemaking does not involve the use of any new
technical standards, but allows for greater flexibility for reporters
to use consensus standards where they are available. Therefore, the EPA
is not considering the use of specific voluntary consensus standards.
J. Executive Order 12898: Federal Actions To Address Environmental
Justice in Minority Populations and Low-Income Populations
Executive Order 12898 (59 FR 7629, (February 16, 1994) establishes
Federal executive policy on environmental justice. Its main provision
directs Federal agencies, to the greatest extent practicable and
permitted by law, to make environmental justice part of their mission
by identifying and addressing, as appropriate, disproportionately high
and adverse human health or environmental effects of their programs,
policies, and activities on minority populations and low-income
populations in the United States.
The EPA has determined that this proposed rule will not have
disproportionately high and adverse human health or environmental
effects on minority or low-income populations because it does not
affect the level of protection provided to human health or the
environment because it is a rule addressing information collection and
reporting procedures.
List of Subjects 40 CFR Part 98
Environmental protection, Administrative practice and procedure,
Greenhouse gases, Suppliers, Reporting and recordkeeping requirements.
Dated: March 8, 2013.
Bob Perciasepe,
Acting Administrator.
For the reasons stated in the preamble, title 40, chapter I, of the
Code of Federal Regulations is proposed to be amended as follows:
PART 98--[AMENDED]
0
1. The authority citation for part 98 continues to read as follows:
Authority: 42 U.S.C. 7401, et seq.
Subpart A--[AMENDED]
0
2. Section 98.3 is amended by:
0
a. Revising paragraph (c)(1).
0
b. Adding paragraphs (c)(11)(viii) and (c)(13).
0
c. Revising paragraphs (h)(4), and (j)(3)(ii).
0
d. Adding paragraphs (k) and (l).
Sec. 98.3 What are the general monitoring, reporting, recordkeeping
and verification requirements of this part?
* * * * *
(c) * * *
(1) Facility name or supplier name (as appropriate), and physical
street address of the facility or supplier, including the city, State,
and zip code. If the facility does not have a physical street address,
then the facility must provide the latitude and longitude representing
the location of facility operations in decimal degree format. This must
be provided in a comma-delimited ``latitude, longitude'' coordinate
pair reported in decimal degrees to at least four digits to the right
of the decimal.
* * * * *
(11) * * *
(viii) The facility or supplier must refer to the reporting
instructions of the electronic GHG reporting tool regarding
standardized conventions for the naming of a parent company.
* * * * *
(13) ORIS code for each power generation unit that has been
assigned an ORIS code by the Energy Information Administration.
* * * * *
(h) * * *
(4) Notwithstanding paragraphs (h)(1) and (h)(2) of this section,
upon request by the owner or operator, the Administrator may provide
reasonable extensions of the 45-day period for submission of the
revised report or information under paragraphs (h)(1) and (h)(2) of
this section. If the Administrator receives a request for extension of
the 45-day period, by email to an address prescribed by the
Administrator prior to the expiration of the 45-day period, the
extension request is deemed to be automatically granted for 30 days.
The Administrator may grant an additional extension beyond the
automatic 30-day extension if the owner or operator submits a request
for an additional extension and the request is received by the
Administrator at least 5 business days prior to the expiration of the
automatic 30-day extension, provided the request demonstrates that it
is not practicable to submit a revised report or information under
paragraphs (h)(1) and (h)(2) within 75 days. The Administrator will
approve the extension request if the request demonstrates that it is
not practicable to collect and process the data needed to resolve
potential reporting errors identified pursuant to paragraphs (h)(1) or
(h)(2) of this section within 75 days.
* * * * *
(j) * * *
(3) * * *
(ii) Any subsequent extensions to the original request must be
submitted to the Administrator within 4 weeks of the owner or operator
identifying the need to extend the request, but in any event no later
than 4 weeks before the date for the planned process equipment or unit
shutdown that was provided in the original or most recently approved
request.
* * * * *
(k) Revised Global Warming Potentials--(1) General. Starting with
reporting year 2013, facilities and suppliers must use the revised GWPs
in Table A-1 of this subpart, Global Warming Potentials, for
calculating CO2e emissions for determining applicability to
this part and for calculating CO2e emissions in annual GHG
reports.
(2) Special provision for reporting year 2013. A facility or
supplier that was not subject to a subpart of part 98 for reporting
year 2012, but becomes subject to a subpart of this part due to a
change in the GWP for one or more compounds in Table A-1 of this
subpart, Global Warming Potentials, is not required to submit an annual
GHG for reporting year 2013. Such facilities or suppliers must start
monitoring and collecting GHG data in compliance with this part
starting on January 1, 2014, and submit an annual greenhouse gas report
for reporting year 2014 by March 31, 2015.
(l) Special provision for best available monitoring methods in
2014. This paragraph (l) applies to owners or operators of facilities
or suppliers that first become subject to any subpart of part 98 due to
an amendment to Table A-1 of this subpart, Global Warming Potentials.
(1) Best available monitoring methods. From January 1, 2014 to
March 31, 2014, owners or operators subject to this paragraph (l) may
use best available monitoring methods for any parameter (e.g., fuel
use, feedstock rates) that cannot reasonably be measured according to
the monitoring and QA/QC requirements of a relevant subpart. The owner
or operator must use the calculation methodologies and equations in the
``Calculating GHG Emissions'' sections of each relevant subpart, but
may use the best available monitoring method for any parameter for
which it is not reasonably feasible to acquire, install, and operate a
required
[[Page 19845]]
piece of monitoring equipment by January 1, 2014. Starting no later
than April 1, 2014, the owner or operator must discontinue using best
available methods and begin following all applicable monitoring and QA/
QC requirements of this part, except as provided in paragraph (l)(2) of
this section. Best available monitoring methods means any of the
following methods:
(i) Monitoring methods currently used by the facility that do not
meet the specifications of a relevant subpart.
(ii) Supplier data.
(iii) Engineering calculations.
(iv) Other company records.
(2) Requests for extension of the use of best available monitoring
methods. The owner or operator may submit a request to the
Administrator to use one or more best available monitoring methods
beyond March 31, 2014.
(i) Timing of request. The extension request must be submitted to
EPA no later than January 31, 2014.
(ii) Content of request. Requests must contain the following
information:
(A) A list of specific items of monitoring instrumentation for
which the request is being made and the locations where each piece of
monitoring instrumentation will be installed.
(B) Identification of the specific rule requirements (by rule
subpart, section, and paragraph numbers) for which the instrumentation
is needed.
(C) A description of the reasons that the needed equipment could
not be obtained and installed before April 1, 2014.
(D) If the reason for the extension is that the equipment cannot be
purchased and delivered by April 1, 2014, supporting documentation such
as the date the monitoring equipment was ordered, investigation of
alternative suppliers and the dates by which alternative vendors
promised delivery, backorder notices or unexpected delays, descriptions
of actions taken to expedite delivery, and the current expected date of
delivery.
(E) If the reason for the extension is that the equipment cannot be
installed without a process unit shutdown, include supporting
documentation demonstrating that it is not practicable to isolate the
equipment and install the monitoring instrument without a full process
unit shutdown. Include the date of the most recent process unit
shutdown, the frequency of shutdowns for this process unit, and the
date of the next planned shutdown during which the monitoring equipment
can be installed. If there has been a shutdown or if there is a planned
process unit shutdown between April 2, 2013 and April 1, 2014, include
a justification of why the equipment could not be obtained and
installed during that shutdown.
(F) A description of the specific actions the facility will take to
obtain and install the equipment as soon as reasonably feasible and the
expected date by which the equipment will be installed and operating.
(iii) Approval criteria. To obtain approval, the owner or operator
must demonstrate to the Administrator's satisfaction that it is not
reasonably feasible to acquire, install, and operate a required piece
of monitoring equipment by April 1, 2014. The use of best available
methods under this paragraph (l) will not be approved beyond December
31, 2014.
0
3. Section 98.6 is amended by:
0
a. Revising the definitions for ``Continuous bleed'', ``Degasification
system'', and ``Intermittent bleed pneumatic devices''.
0
b. Adding the definitions of ``Fluidized Bed Combustor (FBC)'' and
``ORIS code'' in alphabetical order.
0
c. Revising the term ``Ventilation well or shaft'' to read
``Ventilation hole or shaft'' and revising the definition of the term.
0
d. Revising the definition of ``Ventilation system''.
Sec. 98.6 Definitions.
* * * * *
Continuous bleed means a continuous flow of pneumatic supply
natural gas to the process control device (e.g. level control,
temperature control, pressure control) where the supply gas pressure is
modulated by the process condition, and then flows to the valve
controller where the signal is compared with the process set-point to
adjust gas pressure in the valve actuator.
* * * * *
Degasification system means the entirety of the equipment that is
used to drain gas from underground coal mines. This includes all
degasification wells and gob gas vent holes at the underground coal
mine. Degasification systems include gob and premine surface drainage
wells, gob and premine in-mine drainage wells, and in-mine gob and
premine cross-measure borehole wells.
* * * * *
Fluidized Bed Combustor (FBC) means a combustion technology (e.g.,
a fluidized bed boiler) where the maximum steady-state temperature
reached within the combustor (excluding periods of startup, shutdown,
and malfunction) during the combustion of solid fuels (e.g., coal, tire
derived fuel, wood and wood residuals, agricultural byproducts, coke,
municipal solid waste, or mixtures of such fuels) is less than or equal
to 1,900 degrees Fahrenheit.
* * * * *
Intermittent bleed pneumatic devices mean automated flow control
devices powered by pressurized natural gas and used for automatically
maintaining a process condition such as liquid level, pressure, delta-
pressure and temperature. These are snap-acting or throttling devices
that discharge all or a portion of the full volume of the actuator
intermittently when control action is necessary, but does not bleed
continuously.
* * * * *
ORIS code means the unique identifier assigned to each power plant
in the National Electric Energy Data System (NEEDS). The ORIS code is a
four-digit number assigned by the Energy Information Administration
(EIA) at the US Department of Energy to power plants owned by
utilities.
* * * * *
Ventilation hole or shaft means a vent hole or shaft employed at an
underground coal mine to serve as the outlet or conduit to move air
from the ventilation system out of the mine.
Ventilation system means a system that is used to control the
concentration of methane and other gases within mine working areas
through mine ventilation, rather than a mine degasification system. A
ventilation system consists of fans that move air through the mine
workings to dilute methane concentrations.
* * * * *
0
4a. Table A-1 to Subpart A is revised to read as follows:
[[Page 19846]]
Table A-1 to Subpart A of Part 98--Global Warming Potentials
[100-Year Time Horizon]
----------------------------------------------------------------------------------------------------------------
Global
warming
Name CAS No. Chemical formula potential (100
yr.)
----------------------------------------------------------------------------------------------------------------
Carbon dioxide............................. 124-38-9 CO2................................ 1
Methane.................................... 74-82-8 CH4................................ a 25
Nitrous oxide.............................. 10024-97-2 N2O................................ a 298
HFC-23..................................... 75-46-7 CHF3............................... a 14,800
HFC-32..................................... 75-10-5 CH2F2.............................. a 675
HFC-41..................................... 593-53-3 CH3F............................... a 92
HFC-125.................................... 354-33-6 C2HF5.............................. a 3,500
HFC-134.................................... 359-35-3 C2H2F4............................. a 1,100
HFC-134a................................... 811-97-2 CH2FCF3............................ a 1,430
HFC-143.................................... 430-66-0 C2H3F3............................. a 353
HFC-143a................................... 420-46-2 C2H3F3............................. a 4,470
HFC-152.................................... 624-72-6 CH2FCH2F........................... 53
HFC-152a................................... 75-37-6 CH3CHF2............................ a 124
HFC-161.................................... 353-36-6 CH3CH2F............................ 12
HFC-227ea.................................. 431-89-0 C3HF7.............................. a 3,220
HFC-236cb.................................. 677-56-5 CH2FCF2CF3......................... 1,340
HFC-236ea.................................. 431-63-0 CHF2CHFCF3......................... 1,370
HFC-236fa.................................. 690-39-1 C3H2F6............................. a 9,810
HFC-245ca.................................. 679-86-7 C3H3F5............................. a 693
HFC-245fa.................................. 460-73-1 CHF2CH2CF3......................... 1,030
HFC-365mfc................................. 406-58-6 CH3CF2CH2CF3....................... 794
HFC-43-10mee............................... 138495-42-8 CF3CFHCFHCF2CF3.................... a 1,640
Sulfur hexafluoride........................ 2551-62-4 SF6................................ a 22,800
Trifluoromethyl sulphur pentafluoride...... 373-80-8 SF5CF3............................. 17,700
Nitrogen trifluoride....................... 7783-54-2 NF3................................ 17,200
PFC-14 (Perfluoromethane).................. 75-73-0 CF4................................ a 7,390
PFC-116 (Perfluoroethane).................. 76-16-4 C2F6............................... a 12,200
PFC-218 (Perfluoropropane)................. 76-19-7 C3F8............................... a 8,830
Perfluorocyclopropane...................... 931-91-9 C-C3F6............................. 17,340
PFC-3-1-10 (Perfluorobutane)............... 355-25-9 C4F10.............................. a 8,860
Perfluorocyclobutane....................... 115-25-3 C-C4F8............................. a 10,300
PFC-4-1-12 (Perfluoropentane).............. 678-26-2 C5F12.............................. a 9,160
PFC-5-1-14 (Perfluorohexane)............... 355-42-0 C6F14.............................. a 9,300
PFC-9-1-18................................. 306-94-5 C10F18............................. 7,500
HCFE-235da2 (Isoflurane)................... 26675-46-7 CHF2OCHClCF3....................... 350
HFE-43-10pccc (H-Galden 1040x)............. E1730133 CHF2OCF2OC2F4OCHF2................. 1,870
HFE-125.................................... 3822-68-2 CHF2OCF3........................... 14,900
HFE-134.................................... 1691-17-4 CHF2OCHF2.......................... 6,320
HFE-143a................................... 421-14-7 CH3OCF3............................ 756
HFE-227ea.................................. 2356-62-9 CF3CHFOCF3......................... 1,540
HFE-236ca12 (HG-10)........................ 78522-47-1 CHF2OCF2OCHF2...................... 2,800
HFE-236ea2 (Desflurane).................... 57041-67-5 CHF2OCHFCF3........................ 989
HFE-236fa.................................. 20193-67-3 CF3CH2OCF3......................... 487
HFE-245cb2................................. 22410-44-2 CH3OCF2CF3......................... 708
HFE-245fa1................................. 84011-15-4 CHF2CH2OCF3........................ 286
HFE-245fa2................................. 1885-48-9 CHF2OCH2CF3........................ 659
HFE-254cb2................................. 425-88-7 CH3OCF2CHF2........................ 359
HFE-263fb2................................. 460-43-5 CF3CH2OCH3......................... 11
HFE-329mcc2................................ 67490-36-2 CF3CF2OCF2CHF2..................... 919
HFE-338mcf2................................ 156053-88-2 CF3CF2OCH2CF3...................... 552
HFE-338pcc13 (HG-01)....................... 188690-78-0 CHF2OCF2CF2OCHF2................... 1,500
HFE-347mcc3................................ 28523-86-6 CH3OCF2CF2CF3...................... 575
HFE-347mcf2................................ E1730135 CF3CF2OCH2CHF2..................... 374
HFE-347pcf2................................ 406-78-0 CHF2CF2OCH2CF3..................... 580
HFE-356mec3................................ 382-34-3 CH3OCF2CHFCF3...................... 101
HFE-356pcc3................................ 160620-20-2 CH3OCF2CF2CHF2..................... 110
HFE-356pcf2................................ E1730137 CHF2CH2OCF2CHF2.................... 265
HFE-356pcf3................................ 35042-99-0 CHF2OCH2CF2CHF2.................... 502
HFE-365mcf3................................ 378-16-5 CF3CF2CH2OCH3...................... 11
HFE-374pc2................................. 512-51-6 CH3CH2OCF2CHF2..................... 557
HFE-449s1 (HFE-7100) Chemical blend........ 163702-07-6 C4F9OCH3(CF3)2CFCF2OCH3............ 297
163702-08-7
HFE-569sf2 (HFE-7200) Chemical blend....... 163702-05-4 C4F9OC2H5(CF3)2CFCF2OC2H5.......... 59
163702-06-5
Sevoflurane................................ 28523-86-6 CH2FOCH(CF3)2...................... 345
HFE-356mm1................................. 13171-18-1 (CF3)2CHOCH3....................... 27
HFE-338mmz1................................ 26103-08-2 CHF2OCH(CF3)2...................... 380
(Octafluorotetramethy-lene)hydroxymethyl NA X-(CF2)4CH(OH)-X................... 73
group.
[[Page 19847]]
HFE-347mmy1................................ 22052-84-2 CH3OCF(CF3)2....................... 343
Bis(trifluoromethyl)-methanol.............. 920-66-1 (CF3)2CHOH......................... 195
2,2,3,3,3-pentafluoropropanol.............. 422-05-9 CF3CF2CH2OH........................ 42
PFPMIE..................................... NA CF3OCF(CF3)CF2OCF2OCF3............. 10,300
HFC-1234ze b............................... 29118-24-9 C3H2F4............................. 6
hexafluoropropylene (HFP) b................ 116-15-4 C3F6............................... 0.25
perfluoromethyl vinyl ether (PMVE) b....... 1187-93-5 CF(CF3)OCF3........................ 3
tetrafluoroethylene (TFE) b................ 116-14-3 C2F4............................... 0.02
trifluoro propene (TFP) b.................. 677-21-4 C3H3F3............................. 3
vinyl fluoride (VF) b...................... 75-02-5 C2H3F.............................. 0.7
vinylidiene fluoride (VF2) b............... 75-38-7 C2H2F2............................. 0.9
carbonyl fluoride b........................ 353-50-4 COF2............................... 2
perfluoropropyl vinyl ether b.............. 1623-05-8 C5F10O............................. 3
perfluoroethyl vinyl ether b............... 10493-43-3 C4F8O.............................. 3
HFC-1234yf b............................... 754-12-1 C3H2F4............................. 4
perfluorethyl iodide (2-I) b............... 354-64-3 C2F5I.............................. 3
perfluorbutyl iodide (PFBI, 42-I) b........ 423-39-2 C4F9I.............................. 3
perfluorhexyl iodide (6-I) b............... 355-43-1 CF3CF2CF2CF2CF2CF2IC6F13I.......... 2
perfluoroctyl iodide (8-I) b............... 507-63-1 C8F17I............................. 2
1,1,1,2,2-pentafluoro-4-iodo butane (22-I) 40723-80-6 C4H4F5I............................ 2
b.
1,1,1,2,2,3,3,4,4-nonafluoro-6-iodo hexane 2043-55-2 C6H4F9I............................ 2
(42-I) b.
perfluorobutyl ethene (42-U) b............. 19430-93-4 C6H3F9............................. 2
perfluorohexyl ethene (62-U) b............. 25291-17-2 C8H3F13............................ 1
perfluorooctyl ethene (82-U) b............. 21652-58-4 C10H3F17........................... 1
1H,1H, 2H,2H-perfluorohexan-1-ol (42-AL) b. 2043-47-2 C6H5F9O............................ 5
FK-5-1-12 Perfluoroketone; FK-5-1-12myy2; n- 756-13-8 CF3CF2C(O)CF(CF3)2................. 1.8
Perfluorooctane; Octanedecafluorooctane b.
C7 Fluoroketone, Novec 774/FK-6-1-12....... 813-44-5 and C7F14O Chemical Blend.............. 1
813-45-6
trans-1-chloro-3,3,3-trifluoroprop-1-ene b. 2730-43-0 C3H2ClF3........................... 7
Hexadecofluoroheptane b (PFC-6-1-12)....... 335-57-9 C7F16.............................. 7930
octadecafluorooctane b (PFC-7-1-18)........ 307-34-6 C8F18.............................. 8340
----------------------------------------------------------------------------------------------------------------
a The GWP for this compound is different than the GWP in the version of Table A-1 to subpart A of part 98
published on October 30, 2009.
b The GWP for this compound was not provided in the version of Table A-1 to subpart A of part 98 published on
October 30, 2009.
NA--Not available.
0
4b. Table A-6 is amended by revising the entries for 98.346(d)(1) and
98.346(e) to read as follows:
Table A-6 to Subpart A of Part 98--Data Elements That Are Inputs to
Emission Equations and for Which the Reporting Deadline Is March 31,
2013
------------------------------------------------------------------------
Specific data elements for
which reporting date is
March 31, 2013 (``All''
Subpart Rule citation (40 CFR means all data elements in
part 98) the cited paragraph are not
required to be reported
until March 31, 2013)
------------------------------------------------------------------------
* * * * * * *
HH................ 98.346(d)(1)........... Only degradable organic
carbon (DOC) value, and
fraction of DOC
dissimilated (DOCF)
values.
* * * * * * *
HH................ 98.346(e).............. Only fraction of CH4 in
landfill gas and methane
correction factor (MCF)
values.
* * * * * * *
------------------------------------------------------------------------
Subpart C--[AMENDED]
0
5. Section 98.33 is amended by:
0
a. Adding paragraphs (b)(1)(viii) and (ix).
0
b. Revising paragraphs (b)(3)(ii)(A), (e)(1)(ii), and (e)(3)(iv)(B).
Sec. 98.33 Calculating GHG emissions.
* * * * *
(b) * * *
(1) * * *
(viii) May be used for the combustion of a fuel listed in Table C-1
if the fuel is combusted in a unit with a maximum rated heat input
capacity greater than 250 mmBtu/hr (or, pursuant to Sec. 98.36(c)(3),
in a group of units served by a common supply pipe, having at least one
unit with a maximum rated heat input capacity greater than 250
[[Page 19848]]
mmBtu/hr), provided that both of the following conditions apply:
(A) The use of Tier 4 is not required.
(B) The fuel provides less than 10 percent of the annual heat input
to the unit, or if Sec. 98.36(c)(3) applies, to the group of units
served by a common supply pipe.
(ix) May not be used for the combustion of waste coal (i.e., waste
anthracite (culm) and waste bituminous (gob)).
* * * * *
(3) * * *
(ii) * * *
(A) The use of Tier 1 or 2 is permitted, as described in paragraphs
(b)(1)(iii), (b)(1)(v), (b)(1)(viii), and (b)(2)(ii) of this section.
* * * * *
(e) * * *
(1) * * *
(ii) The procedures in paragraph (e)(4) of this section.
* * * * *
(3) * * *
(iv) * * *
(B) Multiply the result from paragraph (e)(3)(iv)(A) of this
section by the appropriate default factor to determine the annual
biogenic CO2 emissions, in metric tons. For MSW, use a
default factor of 0.55 and for tires, use a default factor of 0.20.
* * * * *
0
6. Section 98.36 is amended by revising paragraph (b)(3) and the next
to last sentence of paragraph (c)(3) introductory text to read as
follows:
Sec. 98.36 Data reporting requirements.
* * * * *
(b) * * *
(3) Maximum rated heat input capacity of the unit, in mmBtu/hr.
* * * * *
(c) * * *
(3) * * * As a second example, in accordance with Sec.
98.33(b)(1)(v), Tier 1 may be used regardless of unit size when natural
gas is transported through the common pipe, if the annual fuel
consumption is obtained from gas billing records in units of therms or
mmBtu.* * *
* * * * *
0
7. Tables C-1 and C-2 to Subpart C are revised to read as follows:
Table C-1 to Subpart C--Default CO2 Emission Factors and High Heat
Values for Various Types of Fuel
------------------------------------------------------------------------
Default high heat Default CO2
Fuel type value emission factor
------------------------------------------------------------------------
Coal and coke mmBtu/short ton kg CO2/mmBtu
------------------------------------------------------------------------
Anthracite...................... 25.09.............. 103.69
Waste Anthracite (Culm)......... See footnote 1..... 103.69
Bituminous...................... 24.93.............. 93.28
Waste Bituminous (Gob).......... See footnote 1..... 93.28
Subbituminous................... 17.25.............. 97.17
Lignite......................... 14.21.............. 97.72
Coal Coke....................... 24.80.............. 113.67
Mixed (Commercial sector)....... 21.39.............. 94.27
Mixed (Industrial coking)....... 26.28.............. 93.90
Mixed (Industrial sector)....... 22.35.............. 94.67
Mixed (Electric Power sector)... 19.73.............. 95.52
------------------------------------------------------------------------
Natural gas mmBtu/scf kg CO2/mmBtu
------------------------------------------------------------------------
(Weighted U.S. Average)......... 1.026 x 10-3....... 53.06
------------------------------------------------------------------------
Petroleum products mmBtu/gallon kg CO2/mmBtu
------------------------------------------------------------------------
Distillate Fuel Oil No. 1....... 0.139.............. 73.25
Distillate Fuel Oil No. 2....... 0.138.............. 73.96
Distillate Fuel Oil No. 4....... 0.146.............. 75.04
Residual Fuel Oil No. 5......... 0.140.............. 72.93
Residual Fuel Oil No. 6......... 0.150.............. 75.10
Used Oil........................ 0.138.............. 74.00
Kerosene........................ 0.135.............. 75.20
Liquefied petroleum gases 0.092.............. 61.71
(LPG)\2\.
Propane \2\..................... 0.091.............. 62.87
Propylene \2\................... 0.091.............. 67.77
Ethane \2\...................... 0.068.............. 59.60
Ethanol......................... 0.084.............. 68.44
Ethylene \3\.................... 0.058.............. 65.96
Isobutane \2\................... 0.099.............. 64.94
Isobutylene \2\................. 0.103.............. 68.86
Butane \2\...................... 0.103.............. 64.77
Butylene \2\.................... 0.105.............. 68.72
Naphtha (<401 deg F)............ 0.125.............. 68.02
Natural Gasoline................ 0.110.............. 66.88
Other Oil (>401 deg F).......... 0.139.............. 76.22
Pentanes Plus................... 0.110.............. 70.02
Petrochemical Feedstocks........ 0.125.............. 71.02
Petroleum Coke.................. 0.143.............. 102.41
Special Naphtha................. 0.125.............. 72.34
Unfinished Oils................. 0.139.............. 74.54
Heavy Gas Oils.................. 0.148.............. 74.92
Lubricants...................... 0.144.............. 74.27
Motor Gasoline.................. 0.125.............. 70.22
[[Page 19849]]
Aviation Gasoline............... 0.120.............. 69.25
Kerosene-Type Jet Fuel.......... 0.135.............. 72.22
Asphalt and Road Oil............ 0.158.............. 75.36
Crude Oil....................... 0.138.............. 74.54
------------------------------------------------------------------------
Other fuels-solid mmBtu/short ton kg CO2/mmBtu
------------------------------------------------------------------------
Municipal Solid Waste........... 9.95 \4\........... 90.7
Tires........................... 28.00.............. 85.97
Plastics........................ 38.00.............. 75.00
Petroleum Coke.................. 30.00.............. 102.41
------------------------------------------------------------------------
Other fuels--gaseous mmBtu/scf kg CO2/mmBtu
Blast Furnace Gas............... 0.092 x 10-3....... 274.32
Coke Oven Gas................... 0.599 x 10-3....... 46.85
Propane Gas..................... 2.516 x 10-3....... 61.46
Fuel Gas \5\.................... 1.388 x 10-3....... 59.00
------------------------------------------------------------------------
Biomass fuels--solid mmBtu/short ton kg CO2/mmBtu
------------------------------------------------------------------------
Wood and Wood Residuals(dry 17.48.............. 93.80
basis)\6\.
Agricultural Byproducts......... 8.25............... 118.17
Peat............................ 8.00............... 111.84
Solid Byproducts................ 10.39.............. 105.51
------------------------------------------------------------------------
Biomass fuels--gaseous mmBtu/scf kg CO2/mmBtu
------------------------------------------------------------------------
Landfill Gas.................... 0.485 x 10-3....... 52.07
Other Biomass Gases............. 0.655 x 10-3....... 52.07
------------------------------------------------------------------------
Biomass Fuels--liquid mmBtu/gallon kg CO2/mmBtu
------------------------------------------------------------------------
Ethanol......................... 0.084.............. 68.44
Biodiesel (100%)................ 0.128.............. 73.84
Rendered Animal Fat............. 0.125.............. 71.06
Vegetable Oil................... 0.120.............. 81.55
------------------------------------------------------------------------
\1\ Provisions of the rule referencing ``default HHVs from Table C-1''
do not apply to culm and gob. The HHV for culm and gob must be
determined according to the procedures specified in the Tier 2
Calculation Methodology.
\2\ The HHV for components of LPG determined at 60 [deg]F and saturation
pressure with the exception of ethylene.
\3\ Ethylene HHV determined at 41 [deg]F (5 [deg]C) and saturation
pressure.
\4\ Use of this default HHV is allowed only for: (a) Units that combust
MSW, do not generate steam, and are allowed to use Tier 1; (b) units
that derive no more than 10 percent of their annual heat input from
MSW and/or tires; and (c) small batch incinerators that combust no
more than 1,000 tons of MSW per year.
\5\ Reporters subject to subpart X of this part that are complying with
Sec. 98.243(d) or subpart Y of this part may only use the default
HHV and the default CO2 emission factor for fuel gas combustion under
the conditions prescribed in Sec. 98.243(d)(2)(i) and (d)(2)(ii) and
Sec. 98.252(a)(1) and (a)(2), respectively. Otherwise, reporters
subject to subpart X or subpart Y shall use either Tier 3 (Equation C-
5) or Tier 4.
\6\ Use the following formula to calculate a wet basis HHV for use in
Equation C-1: HHVw = ((100-M)/100)*HHVd where HHVw = wet basis HHV, M
= moisture content(percent) and HHVd = dry basis HHV from Table C-1.
Table C-2 to Subpart C--Default CH4 and N2O Emission Factors for Various
Types of Fuel
------------------------------------------------------------------------
Default CH4 Default N2O
Fuel type emission factor emission factor
(kg CH4/mmBtu) (kg N2O/mmBtu)
------------------------------------------------------------------------
Coal and Coke (All fuel types in 1.1 x 10-\02\ 1.6 x 10-\03\
Table C-1) \1\.....................
Anthracite for FBCs only \2\........ 1.1 x 10-\02\ 1.6 x 10-\01\
Waste Anthracite (Culm) for FBCs 1.1 x 10-\02\ 4.0 x 10-\01\
only \2\...........................
Bituminous for FBCs only \2\........ 1.1 x 10-\02\ 1.3 x 10-\01\
Waste Bituminous (Gob) for FBCs only 1.1 x 10-\02\ 2.9 x 10-\01\
\2\................................
Subbituminous for FBCs only \2\..... 1.1 x 10-\02\ 6.5 x 10-\02\
Lignite for FBCs only \2\........... 1.1 x 10-\02\ 1.1 x 10-\01\
Natural Gas......................... 1.0 x 10-\03\ 1.0 x 10-\04\
Petroleum (All fuel types in Table C- 3.0 x 10-\03\ 6.0 x 10-\04\
1).................................
Fuel Gas............................ 3.0 x 10-\03\ 6.0 x 10-\04\
Municipal Solid Waste............... 3.2 x 10-\02\ 4.2 x 10-\03\
Tires............................... 3.2 x 10-\02\ 4.2 x 10-\03\
Blast Furnace Gas................... 2.2 x 10-\05\ 1.0 x 10-\04\
Coke Oven Gas....................... 4.8 x 10-\04\ 1.0 x 10-\04\
Biomass Fuels--Solid (All fuel types 3.2 x 10-\02\ 4.2 x 10-\03\
in Table C-1, except wood and wood
residuals).........................
[[Page 19850]]
Wood and wood residuals............. 7.2 x 10-\3\ 3.6 x 10-\3\
Biomass Fuels--Gaseous (All fuel 3.2 x 10-\03\ 6.3 x 10-\04\
types in Table C-1)................
Biomass Fuels--Liquid (All fuel 1.1 x 10-\03\ 1.1 x 10-\04\
types in Table C-1)................
------------------------------------------------------------------------
\1\ Use of the default emission factors for the coal and coke category
may not be used to estimate emissions from combusting anthracite,
waste anthracite, bituminous, waste bituminous, subbituminous, or
lignite coal burned in an FBC.
\2\ Use of these default emission factors is required for FBCs burning
the specified coal type.
Note: Those employing this table are assumed to fall under the IPCC
definitions of the ``Energy Industry'' or ``Manufacturing Industries
and Construction''. In all fuels except for coal the values for these
two categories are identical. For coal combustion, those who fall
within the IPCC ``Energy Industry'' category may employ a value of 1g
of CH4/mmBtu.
* * * * *
Subpart E--[AMENDED]
0
8. Section 98.53 is amended by:
0
a. Revising paragraph (b)(3) and paragraph (d) introductory text.
0
b. Revising paragraph (e) and Equation E-2.
0
c. Revising the parameters ``DF'' and ``AF'' of Equation E-3a.
0
d. Revising the parameters ``DF1'', ``AF1'',
``DF2'', ``AF2'', ``DFN'', and
``AFN'' of Equation E-3b.
0
e. Revising the parameters ``DFN'', ``AFN'', and
``FCN'' of Equation E-3c.
Sec. 98.53 Calculating GHG emissions.
* * * * *
(b) * * *
(3) You must measure the adipic acid production rate during the
test and calculate the production rate for the test period in tons per
hour.
* * * * *
(d) If the adipic acid production unit exhausts to any
N2O abatement technology ``N'', you must determine the
destruction efficiency according to paragraphs (d)(1), (d)(2), or
(d)(3) of this section.
* * * * *
(e) If the adipic acid production unit exhausts to any
N2O abatement technology ``N'', you must determine the
annual amount of adipic acid produced while N2O abatement
technology ``N'' is operating according to Sec. 98.54(f). Then you
must calculate the abatement factor for N2O abatement
technology ``N'' according to Equation E-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.000
* * * * *
(g) * * *
(1) * * *
* * * * *
DF = Destruction efficiency of N2O abatement technology
``N'' (decimal fraction of N2O removed from vent stream).
AF = Abatement utilization factor of N2O abatement
technology ``N'' (decimal fraction of time that the abatement
technology is operating).
* * * * *
(2) * * *
* * * * *
DF1 = Destruction efficiency of N2O abatement
technology 1 (decimal fraction of N2O removed from vent
stream).
AF1 = Abatement utilization factor of N2O
abatement technology 1 (decimal fraction of time that abatement
technology 1 is operating).
DF2 = Destruction efficiency of N2O abatement
technology 2 (decimal fraction of N2O removed from vent
stream).
AF2 = Abatement utilization factor of N2O
abatement technology 2 (decimal fraction of time that abatement
technology 2 is operating).
DFN = Destruction efficiency of N2O abatement
technology ``N'' (decimal fraction of N2O removed from
vent stream).
AFN = Abatement utilization factor of N2O
abatement technology ``N'' (decimal fraction of time that abatement
technology N is operating).
* * * * *
(3) * * *
* * * * *
DFN = Destruction efficiency of N2O abatement
technology ``N'' (decimal fraction of N2O removed from
vent stream).
AFN = Abatement utilization factor of N2O
abatement technology ``N'' (decimal fraction of time that the
abatement technology is operating).
FCN = Fraction control factor of N2O abatement
technology ``N'' (decimal fraction of total emissions from unit
``z'' that are sent to abatement technology ``N'').
* * * * *
0
9. Section 98.54 is amended by revising paragraphs (e) and (f) to read
as follows:
Sec. 98.54 Monitoring and QA/QC requirements.
* * * * *
(e) You must determine the monthly amount of adipic acid produced.
You must also determine the monthly amount of adipic acid produced
during which N2O abatement technology is operating. These
monthly amounts are determined according to the methods in paragraphs
(c)(1) or (c)(2) of this section.
(f) You must determine the annual amount of adipic acid produced.
You must also determine the annual amount of adipic acid produced
during which N2O abatement technology is operating. These
are determined by summing the respective monthly adipic acid production
quantities determined in paragraph (e) of this section.
Subpart G--[AMENDED]
0
10. Section 98.73 is amended by:
0
a. Revising paragraph (b)(4) introductory text and revising Equation G-
4.
0
b. Revising Equation G-5 and by removing parameter ``n'' of Equation G-
5 and adding in its place parameter ``j''.
Sec. 98.73 Calculating GHG emissions.
* * * * *
(b) * * *
(4) You must calculate the annual process CO2 emissions
from each ammonia processing unit k at your facility according to
Equation G-4 of this section:
[GRAPHIC] [TIFF OMITTED] TN02AP13.015
* * * * *
(5) * * *
[[Page 19851]]
[GRAPHIC] [TIFF OMITTED] TN02AP13.016
* * * * *
j = Total number of ammonia processing units.
* * * * *
0
11. Section 98.75 is amended by revising paragraph (b) to read as
follows:
Sec. 98.75 Procedures for estimating missing data.
* * * * *
(b) For missing feedstock supply rates used to determine monthly
feedstock consumption or monthly waste recycle stream quantity, you
must determine the best available estimate(s) of the parameter(s),
based on all available process data.
0
12. Section 98.76 is amended by revising paragraphs (a) introductory
text, (b) introductory text, and (b)(13) to read as follows:
Sec. 98.76 Data reporting requirements.
* * * * *
(a) If a CEMS is used to measure CO2 emissions, then you
must report the relevant information required under Sec. 98.36 for the
Tier 4 Calculation Methodology and the information in paragraphs (a)(1)
and (a)(2) of this section:
* * * * *
(b) If a CEMS is not used to measure emissions, then you must
report all of the following information in this paragraph (b):
* * * * *
(13) Annual CO2 emissions (metric tons) from the steam
reforming of a hydrocarbon or the gasification of solid and liquid raw
material at the ammonia manufacturing process unit used to produce urea
and the method used to determine the CO2 consumed in urea
production.
Subpart H--[AMENDED]
0
13. Section 98.86 is amended by revising paragraph (a)(2) to read as
follows:
Sec. 98.86 Data reporting requirements.
* * * * *
(a) * * *
(2) Annual facility cement production.
* * * * *
Subpart K--[AMENDED]
0
14. Section 98.113 is amended by revising Equation K-3 and by removing
the parameter ``2000/2205'' of Equation K-3 and adding in its place the
parameter ``2/2205'' to read as follows:
Sec. 98.113 Calculating GHG emissions.
* * * * *
(d) * * *
(1) * * *
[GRAPHIC] [TIFF OMITTED] TP02AP13.001
* * * * *
2/2205 = Conversion factor to convert kg CH4/ton of
product to metric tons CH4.
* * * * *
0
15. Section 98.116 is amended by adding paragraph (e)(2) to read as
follows:
Sec. 98.116 Data reporting requirements.
* * * * *
(e) * * *
(2) Annual process CH4 emissions (in metric tons) from
each EAF used for the production of any ferroalloy listed in Table K-1
of this subpart.
* * * * *
Subpart L--[AMENDED]
0
16. Section 98.126 is amended by revising paragraphs (j) introductory
text, (j)(1), and (j)(3)(i) to read as follows:
Sec. 98.126 Data reporting requirements.
* * * * *
(j) Special provisions for reporting years 2011, 2012, and 2013
only. For reporting years 2011, 2012, and 2013, the owner or operator
of a facility must comply with paragraphs (j)(1), (j)(2), and (j)(3) of
this section.
(1) Timing. The owner or operator of a facility is not required to
report the data elements at Sec. 98.3(c)(4)(iii) and paragraphs
(a)(2), (a)(3), (a)(4), (a)(6), (b), (c), (d), (e), (f), (g), and (h)
of this section until the later of March 31, 2015 or the date set forth
for that data element at Sec. 98.3(c)(4)(vii) and Table A-7 of Subpart
A of this part.
* * * * *
(3) * * *
(i) If you choose to use a default GWP rather than your best
estimate of the GWP for fluorinated GHGs whose GWPs are not listed in
Table A-1 of Subpart A of this part, use a default GWP of 10,000 for
fluorinated GHGs that are fully fluorinated GHGs and use a default GWP
of 2000 for other fluorinated GHGs.
* * * * *
Subpart N--[AMENDED]
0
17. Section 98.143 is amended by:
0
a. Revising the introductory text.
0
b. Revising paragraph (b) introductory text.
0
c. Revising the parameters ``MFi'' and ``Fi'' of
Equation N-1.
Sec. 98.143 Calculating GHG emissions.
You must calculate and report the annual process CO2
emissions from each continuous glass melting furnace using the
procedure in paragraphs (a) through (c) of this section.
* * * * *
(b) For each continuous glass melting furnace that is not subject
to the requirements in paragraph (a) of this section, calculate and
report the process and combustion CO2 emissions from the
glass melting furnace by using either the procedure in paragraph (b)(1)
of this section or the procedure in paragraph (b)(2) of this section,
except as specified in paragraph (c) of this section.
* * * * *
(2) * * *
(iv) * * *
* * * * *
MFi = Annual average decimal mass fraction of carbonate-
based mineral i in carbonate-based raw material i.
* * * * *
Fi = Decimal fraction of calcination achieved for
carbonate-based raw material i, assumed to be equal to 1.0.
* * * * *
0
18. Section 98.144 is amended by revising paragraph (b) to read as
follows:
Sec. 98.144 Monitoring and QA/QC requirements.
* * * * *
[[Page 19852]]
(b) You must measure carbonate-based mineral mass fractions at
least annually to verify the mass fraction data provided by the
supplier of the raw material; such measurements shall be based on
sampling and chemical analysis using consensus standards that specify
X-ray fluorescence. For measurements made in years prior to the
emissions reporting year 2014, you may also use ASTM D3682-01
(Reapproved 2006) Standard Test Method for Major and Minor Elements in
Combustion Residues from Coal Utilization Processes (incorporated by
reference, see Sec. 98.7) or ASTM D6349-09 Standard Test Method for
Determination of Major and Minor Elements in Coal, Coke, and Solid
Residues from Combustion of Coal and Coke by Inductively Coupled
Plasma--Atomic Emission Spectrometry (incorporated by reference, see
Sec. 98.7).
* * * * *
0
19. Section 98.146 is amended by revising paragraphs (b)(4), (b)(6),
and (b)(7) to read as follows:
Sec. 98.146 Data reporting requirements.
* * * * *
(b) * * *
(4) Carbonate-based mineral decimal mass fraction for each
carbonate-based raw material charged to a continuous glass melting
furnace.
* * * * *
(6) The decimal fraction of calcination achieved for each
carbonate-based raw material, if a value other than 1.0 is used to
calculate process mass emissions of CO2.
(7) Method used to determine decimal fraction of calcination.
* * * * *
0
20. Section 98.147 is amended by revising paragraph (b)(5) to read as
follows:
Sec. 98.147 Records that must be retained.
* * * * *
(b) * * *
(5) The decimal fraction of calcination achieved for each
carbonate-based raw material, if a value other than 1.0 is used to
calculate process mass emissions of CO2.
* * * * *
Subpart O--[AMENDED]
0
21. Section 98.153 is amended by:
0
a. Revising paragraph (c) introductory text.
0
b, Revising paragraph (d) introductory text.
0
c. Revising the parameter ``ED'' of Equation O-5.
Sec. 98.153 Calculating GHG emissions.
* * * * *
(c) For HCFC-22 production facilities that do not use a destruction
device or that have a destruction device that is not directly connected
to the HCFC-22 production equipment, HFC-23 emissions shall be
estimated using Equation O-4 of this section:
* * * * *
(d) For HCFC-22 production facilities that use a destruction device
connected to the HCFC-22 production equipment, HFC-23 emissions shall
be estimated using Equation O-5 of this section:
* * * * *
ED = Mass of HFC-23 emitted annually from destruction
device (metric tons), calculated using Equation O-8 of this section.
* * * * *
0
22. Section 98.154 is amended by revising paragraph (j) to read as
follows:
Sec. 98.154 Monitoring and QA/QC requirements.
* * * * *
(j) The number of sources of equipment type t with screening values
less than 10,000 ppmv shall be the difference between the number of
leak sources of equipment type t that could emit HFC-23 and the number
of sources of equipment type t with screening values greater than or
equal to 10,000 ppmv as determined under paragraph (i) of this section.
* * * * *
0
23. Section 98.156 is amended by revising paragraph (c) to read as
follows:
Sec. 98.156 Data reporting requirements.
* * * * *
(c) Each HFC-23 destruction facility shall report the concentration
(mass fraction) of HFC-23 measured at the outlet of the destruction
device during the facility's annual HFC-23 concentration measurements
at the outlet of the device. If the concentration of HFC-23 is below
the detection limit of the measuring device, report the detection limit
and that the concentration is below the detection limit.
* * * * *
Subpart P--[AMENDED]
0
24. Section 98.163 is amended by:
0
a. Revising paragraph (b) introductory text.
0
b. Revising the parameters ``Fdstkn'', ``CCn'',
and ``MWn'' of Equation P-1.
0
c. Revising the parameters ``Fdstkn'' and ``CCn''
of Equation P-2.
0
d. Revising the parameters ``Fdstkn'' and ``CCn''
of Equation P-3.
Sec. 98.163 Calculating GHG emissions.
* * * * *
(b) Fuel and feedstock material balance approach. Calculate and
report CO2 emissions as the sum of the annual emissions
associated with each fuel and feedstock used for hydrogen production by
following paragraphs (b)(1) through (b)(3) of this section. The carbon
content and molecular weight shall be obtained from the analyses
conducted in accordance with Sec. 98.164(b)(2), (b)(3), or (b)(4), as
applicable, or from the missing data procedures in Sec. 98.165. If the
analyses are performed annually, then the annual value shall be used as
the monthly average. If the analyses are performed more frequently than
monthly, use the arithmetic average of values obtained during the month
as the monthly average.
(1) * * *
* * * * *
Fdstkn = Volume of the gaseous fuel or feedstock used in
month n (scf (at standard conditions of 68 [deg]F and atmospheric
pressure) of fuel or feedstock).
CCn = Average carbon content of the gaseous fuel and
feedstock for month n (kg carbon per kg of fuel or feedstock).
MWn = Average molecular weight of the gaseous fuel or
feedstock for month n (kg/kg-mole).
* * * * *
(2) * * *
* * * * *
Fdstkn = Volume of the liquid fuel or feedstock used in
month n (gallons of fuel or feedstock).
CCn = Average carbon content of the liquid fuel or
feedstock, for month n (kg carbon per gallon of fuel or feedstock).
* * * * *
(3) * * *
* * * * *
Fdstkn = Mass of solid fuel or feedstock used in month n
(kg of fuel or feedstock).
CCn = Average carbon content of the solid fuel or
feedstock, for month n (kg carbon per kg of fuel or feedstock).
* * * * *
0
25. Section 98.164 is amended by:
0
a. Revising paragraphs (b)(3),(b)(4), and (b)(5) introductory text.
0
b. Removing paragraphs (c) and (d).
Sec. 98.164 Monitoring and QA/QC requirements.
* * * * *
(b) * * *
(3) Determine the carbon content of fuel oil, naphtha, and other
liquid fuels and feedstocks at least monthly, except annually for
standard liquid hydrocarbon fuels and feedstocks having consistent
composition, or upon delivery for liquid fuels and feedstocks delivered
by bulk transport (e.g., by truck or rail).
[[Page 19853]]
(4) Determine the carbon content of coal, coke, and other solid
fuels and feedstocks at least monthly, except annually for standard
solid hydrocarbon fuels and feedstocks having consistent composition,
or upon delivery for solid fuels and feedstocks delivered by bulk
transport (e.g., by truck or rail).
(5) You must use the following applicable methods to determine the
carbon content for all fuels and feedstocks, and molecular weight of
gaseous fuels and feedstocks. Alternatively, you may use the results of
chromatographic analysis of the fuel and feedstock, provided that the
chromatograph is operated, maintained, and calibrated according to the
manufacturer's instructions; and the methods used for operation,
maintenance, and calibration of the chromatograph are documented in the
written monitoring plan for the unit under Sec. 98.3(g)(5).
* * * * *
0
26. Section 98.166 is amended by revising paragraphs (a)(2) and (a)(3)
to read as follows:
Sec. 98.166 Data reporting requirements.
* * * * *
(a) * * *
(2) Annual quantity of hydrogen produced (metric tons) for each
process unit.
(3) Annual quantity of ammonia produced (metric tons), if
applicable, for each process unit.
* * * * *
0
27. Section 98.167 is amended by adding paragraphs (c) and (d) to read
as follows:
Sec. 98.167 Records that must be retained.
* * * * *
(c) For units using the calculation methodologies described
98.163(b), the records required under Sec. 98.3(g) must include both
the company records and a detailed explanation of how company records
are used to estimate the following:
(1) Fuel and feedstock consumption, when solid fuel and feedstock
is combusted and a CEMS is not used to measure GHG emissions.
(2) Fossil fuel consumption, when, pursuant to Sec. 98.33(e), the
owner or operator of a unit that uses CEMS to quantify CO2
emissions and that combusts both fossil and biogenic fuels separately
reports the biogenic portion of the total annual CO2
emissions.
(3) Sorbent usage, if the methodology in Sec. 98.33(d) is used to
calculate CO2 emissions from sorbent.
(d) The owner or operator must document the procedures used to
ensure the accuracy of the estimates of fuel and feedstock usage and
sorbent usage (as applicable) in Sec. 98.163(b), including, but not
limited to, calibration of weighing equipment, fuel and feedstock flow
meters, and other measurement devices. The estimated accuracy of
measurements made with these devices must also be recorded, and the
technical basis for these estimates must be provided.
Subpart Q--[AMENDED]
0
28. Section 98.170 is amended by revising the first sentence to read as
follows:
Sec. 98.170 Definition of the source category.
The iron and steel production source category includes facilities
with any of the following processes: taconite iron ore processing,
integrated iron and steel manufacturing, cokemaking not colocated with
an integrated iron and steel manufacturing process, direct reduction
furnaces not collocated with an integrated iron and steel manufacturing
process, and electric arc furnace (EAF) steelmaking not colocated with
an integrated iron and steel manufacturing process. * * *
0
29. Section 98.173 is amended by:
0
a. Revising the parameters ``(Fs)'', ``(Csf)'',
``(Fg)'', ``(Fl)'', ``(C0)'',
``(Cp)'', and ``(CR)'' of Equation Q-1 in
paragraph (b)(1)(i).
0
b. Revising the parameters ``(CIron)'',
``(CScrap)'', ``(CFlux)'',
``(CCarbon)'', ``(CSteel)'',
``(CSlag)'', and ``(CR)'' of Equation Q-2 in
paragraph (b)(1)(ii).
0
c. Revising the parameters ``(CCoal)'',
``(CCoke)'', and ``(CR)'' of Equation Q-3 in
paragraph (b)(1)(iii).
0
d. Revising the parameters ``(Fg)'', ``(CFeed)'',
``(CSinter)'', and ``(CR)'' of Equation Q-4 in
paragraph (b)(1)(iv).
0
e. Revising paragraph (b)(1)(v).
0
f. Revising Equation Q-6 and revising the parameters
``(CSteelin)'', ``(CSteelout)'', and
``(CR)'' of Equation Q-6 in paragraph (b)(1)(vi).
0
g. Revising the parameters ``(Fg)'', ``(COre)'',
``(CCarbon)'', ``(COther)'',
``(CIron)'', ``(CNM)'', and ``(CR)''
of Equation Q-7 in paragraph (b)(1)(vii).
0
h. Revising paragraphs (c) and (d).
Sec. 98.173 Calculating GHG emissions.
* * * * *
(b) * * *
(1) * * *
(i) * * *
* * * * *
(Fs) = Annual mass of the solid fuel used (metric tons).
(Csf) = Carbon content of the solid fuel, from the fuel
analysis (expressed as a decimal fraction).
(Fg) = Annual volume of the gaseous fuel used (scf).
* * * * *
(Fl) = Annual volume of the liquid fuel used (gallons).
* * * * *
(C0) = Carbon content of the greenball (taconite)
pellets, from the carbon analysis results (expressed as a decimal
fraction).
* * * * *
(Cp) = Carbon content of the fired pellets, from the
carbon analysis results (expressed as a decimal fraction).
* * * * *
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
(ii) * * *
* * * * *
(CIron) = Carbon content of the molten iron, from the
carbon analysis results (expressed as a decimal fraction).
* * * * *
(CScrap) = Carbon content of the ferrous scrap, from the
carbon analysis results (expressed as a decimal fraction).
* * * * *
(CFlux) = Carbon content of the flux materials, from the
carbon analysis results (expressed as a decimal fraction).
* * * * *
(CCarbon) = Carbon content of the carbonaceous materials,
from the carbon analysis results (expressed as a decimal fraction).
* * * * *
(CSteel) = Carbon content of the steel, from the carbon
analysis results (expressed as a decimal fraction).
* * * * *
(CSlag) = Carbon content of the slag, from the carbon
analysis (expressed as a decimal fraction).
* * * * *
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
(iii) * * *
* * * * *
(CCoal) = Carbon content of the coal, from the carbon
analysis results (expressed as a decimal fraction).
* * * * *
(CCoke) = Carbon content of the coke, from the carbon
analysis results (expressed as a decimal fraction).
* * * * *
[[Page 19854]]
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
(iv) * * *
* * * * *
(Fg) = Annual volume of the gaseous fuel used (scf).
* * * * *
(CFeed) = Carbon content of the mixed sinter feed
materials that form the bed entering the sintering machine, from the
carbon analysis results (expressed as a decimal fraction).
* * * * *
(CSinter) = Carbon content of the sinter pellets, from
the carbon analysis results (expressed as a decimal fraction).
* * * * *
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
(v) For EAFs, estimate CO2 emissions using Equation Q-5
of this section.
[GRAPHIC] [TIFF OMITTED] TN02AP13.017
Where:
CO2 = Annual CO2 mass emissions from the EAF
(metric tons).
44/12 = Ratio of molecular weights, CO2 to carbon.
(Iron) = Annual mass of direct reduced iron (if any) charged to the
furnace (metric tons).
(CIron) = Carbon content of the direct reduced iron, from
the carbon analysis results (expressed as a decimal fraction).
(Scrap) = Annual mass of ferrous scrap charged to the furnace
(metric tons).
(CScrap) = Carbon content of the ferrous scrap, from the
carbon analysis results (expressed as a decimal fraction).
(Flux) = Annual mass of flux materials (e.g., limestone, dolomite)
charged to the furnace (metric tons).
(CFlux) = Carbon content of the flux materials, from the
carbon analysis results (expressed as a decimal fraction).
(Electrode) = Annual mass of carbon electrode consumed (metric
tons).
(CElectrode) = Carbon content of the carbon electrode,
from the carbon analysis results (expressed as a decimal fraction).
(Carbon) = Annual mass of carbonaceous materials (e.g., coal, coke)
charged to the furnace (metric tons).
(CCarbon) = Carbon content of the carbonaceous materials,
from the carbon analysis results (expressed as a decimal fraction).
(Steel) = Annual mass of molten raw steel produced by the furnace
(metric tons).
(CSteel) = Carbon content of the steel, from the carbon
analysis results (expressed as a decimal fraction).
(Fg) = Annual volume of the gaseous fuel used (scf at 60
degrees F and one atmosphere).
(Cgf) = Average carbon content of the gaseous fuel, from
the fuel analysis results (kg C per kg of fuel).
(MW) = Molecular weight of the gaseous fuel (kg/kg-mole).
(MVC) = Molar volume conversion factor (836.6 scf per kg-mole at
standard conditions of 60 degrees F and one atmosphere).
(0.001) = Conversion factor from kg to metric tons.
(Slag) = Annual mass of slag produced by the furnace (metric tons).
(CSlag) = Carbon content of the slag, from the carbon
analysis results (expressed as a decimal fraction).
(R) = Annual mass of air pollution control residue collected (metric
tons).
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
(vi) * * *
[GRAPHIC] [TIFF OMITTED] TP02AP13.002
* * * * *
(CSteelin) = Carbon content of the molten steel before
decarburization, from the carbon analysis results (expressed as a
decimal fraction).
(CSteelout) = Carbon content of the molten steel after
decarburization, from the carbon analysis results (expressed as a
decimal fraction).
* * * * *
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
(vii) * * *
* * * * *
(Fg) = Annual volume of the gaseous fuel used (scf).
* * * * *
(COre) = Carbon content of the iron ore or iron ore
pellets, from the carbon analysis results (expressed as a decimal
fraction).
* * * * *
(CCarbon) = Carbon content of the carbonaceous materials,
from the carbon analysis results (expressed as a decimal fraction).
* * * * *
(COther) = Average carbon content of the other materials
charged to the furnace, from the carbon analysis results (expressed
as a decimal fraction).
* * * * *
(CIron) = Carbon content of the iron, from the carbon
analysis results (expressed as a decimal fraction).
* * * * *
(CNM) = Carbon content of the non-metallic materials,
from the carbon analysis results (expressed as a decimal fraction).
* * * * *
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).
* * * * *
(c) You must determine emissions of CO2 from the coke
pushing process in mtCO2e by multiplying the metric tons of
coal charged to the by-product recovery and non-recovery coke ovens
during the reporting period by 0.008.
(d) If GHG emissions from a taconite indurating furnace, basic
oxygen furnace, non-recovery coke oven battery, sinter process, EAF,
decarburization vessel, or direct reduction furnace are vented through
a stack equipped with a CEMS that complies with the Tier 4 methodology
in subpart C of this part, or through the same stack as any combustion
unit or process equipment that reports CO2 emissions using a
CEMS that complies with the Tier 4 Calculation Methodology in subpart C
of this part (General Stationary Fuel Combustion Sources), then the
calculation methodology in paragraph (b) of this section shall not be
used to calculate process emissions. The owner
[[Page 19855]]
or operator shall report under this subpart the combined stack
emissions according to the Tier 4 Calculation Methodology in Sec.
98.33(a)(4) and comply with all associated requirements for Tier 4 in
subpart C of this part (General Stationary Fuel Combustion Sources).
0
30. Section 98.174 is amended by revising the last sentence of
paragraph (b)(1), and revising paragraph (c)(2), to read as follows:
Sec. 98.174 Monitoring and QA/QC requirements.
* * * * *
(b) * * *
(1) * * * Determine the mass rate of fuels using the procedures for
combustion units in Sec. 98.34. No determination of the mass of steel
output from decarburization vessels is required.
* * * * *
(c) * * *
(2)(i) For the exhaust from basic oxygen furnaces, EAFs,
decarburization vessels, and direct reduction furnaces, sample the
furnace exhaust for at least three complete production cycles that
start when the furnace is being charged and end after steel or iron and
slag have been tapped. For EAFs that produce both carbon steel and
stainless or specialty (low carbon) steel, develop an emission factor
for the production of both types of steel.
(ii) For the exhaust from continuously charged EAFs, sample the
exhaust for a period spanning at least three hours. For EAFs that
produce both carbon steel and stainless or specialty (low carbon)
steel, develop an emission factor for the production of both types of
steel.
* * * * *
0
31. Section 98.175 is amended by revising paragraph (a) to read as
follows:
Sec. 98.175 Procedures for estimating missing data.
* * * * *
(a) Except as provided in Sec. 98.174(b)(4), 100 percent data
availability is required for the carbon content of inputs and outputs
for facilities that estimate emissions using the carbon mass balance
procedure in Sec. 98.173(b)(1) or facilities that estimate emissions
using the site-specific emission factor procedure in Sec.
98.173(b)(2).
* * * * *
0
32. Section 98.176 is amended by revising paragraph (e) introductory
text to read as follows:
Sec. 98.176 Data reporting requirements.
* * * * *
(e) If you use the carbon mass balance method in Sec. 98.173(b)(1)
to determine CO2 emissions, you must, except as provided in
Sec. 98.174(b)(4), report the following information for each process:
* * * * *
0
33. Section 98.177 is amended by revising paragraph (b) to read as
follows:
Sec. 98.177 Records that must be retained.
* * * * *
(b) When the carbon mass balance method is used to estimate
emissions for a process, the monthly mass of each process input and
output that are used to determine the annual mass, except that no
determination of the mass of steel output from decarburization vessels
is required.
* * * * *
Subpart S--[AMENDED]
0
34. Section 98.190 is amended by revising paragraph (a) to read as
follows:
Sec. 98.190 Definition of the source category.
(a) Lime manufacturing plants (LMPs) engage in the manufacture of a
lime product by calcination of limestone, dolomite, shells or other
calcareous substances as defined in 40 CFR 63.7081(a)(1).
* * * * *
0
35. Section 98.193 is amended by:
0
a. Revising paragraph (a).
0
b. Revising paragraph (b)(1).
0
c. Revising paragraph (b)(2) introductory text.
0
d. Revising paragraph (b)(2)(ii) introductory text.
0
e. Revising the parameters ``EFLKD,i,n'',
``CaOLKD,i,n'' and ``MgOLKD,i,n'' of Equation S-
2.
0
f. Revising paragraph (b)(2)(iii) introductory text.
0
g. Revising the parameters ``Ewaste,i'',
``CaOwaste,i'', ``MgOwaste,i'', and
``Mwaste,i'' of Equation S-3.
0
h. Revising paragraph (b)(2)(iv) introductory text.
0
i. Revising the parameters ``ECO2'',
``EFLKD,i,n'', ``MLKD,i,n'',
``Ewaste,i'', ``b'' and ``z'' of Equation S-4 to read as
follows:
Sec. 98.193 Calculating GHG emissions.
* * * * *
(a) If all lime kilns meet the conditions specified in Sec.
98.33(b)(4)(ii) or (b)(4)(iii), you must calculate and report under
this subpart the combined process and combustion CO2
emissions from all lime kilns by operating and maintaining a CEMS to
measure CO2 emissions according to the Tier 4 Calculation
Methodology specified in Sec. 98.33(a)(4) and all associated
requirements for Tier 4 in subpart C of this part (General Stationary
Fuel Combustion Sources).
(b) * * *
(1) Calculate and report under this subpart the combined process
and combustion CO2 emissions from all lime kilns by
operating and maintaining a CEMS to measure CO2 emissions
from all lime kilns according to the Tier 4 Calculation Methodology
specified in Sec. 98.33(a)(4) and all associated requirements for Tier
4 in subpart C of this part (General Stationary Fuel Combustion
Sources).
(2) Calculate and report process and combustion CO2
emissions from all lime kilns separately using the procedures specified
in paragraphs (b)(2)(i) through (b)(2)(v) of this section.
* * * * *
(ii) You must calculate a monthly emission factor for each type of
calcined byproduct or waste sold (including lime kiln dust) using
Equation S-2 of this section:
* * * * *
EFLKD, i, n = Emission factor for calcined lime byproduct
or waste type i sold, for month n (metric tons CO2/ton
lime byproduct).
CaOLKD, i, n = Calcium oxide content for calcined lime
byproduct or waste type i sold, for month n (metric tons CaO/metric
ton lime).
MgOLKD, i ,n = Magnesium oxide content for calcined lime
byproduct or waste type i sold, for month n (metric tons MgO/metric
ton lime).
* * * * *
(iii) You must calculate the annual CO2 emissions from
each type of calcined byproduct or waste that is not sold (including
lime kiln dust and scrubber sludge) using Equation S-3 of this section:
* * * * *
Ewaste, i = Annual CO2 emissions for calcined
lime byproduct or waste type i that is not sold (metric tons
CO2).
* * * * *
CaOwaste, i = Calcium oxide content for calcined lime
byproduct or waste type i that is not sold (metric tons CaO/metric
ton lime).
MgOwaste, i = Magnesium oxide content for calcined lime
byproduct or waste type i that is not sold (metric tons MgO/metric
ton lime).
Mwaste, i = Annual weight or mass of calcined byproducts
or wastes for lime type i that is not sold (tons).
* * * * *
(iv) You must calculate annual CO2 process emissions for
all lime kilns using Equation S-4 of this section:
* * * * *
[[Page 19856]]
ECO2 = Annual CO2 process emissions from lime
production from all lime kilns (metric tons/year).
* * * * *
EFLKD, i, n = Emission factor of calcined byproducts or
wastes sold for lime type i in calendar month n, (metric tons
CO2/ton byproduct or waste) from Equation S-2 of this
section.
MLKD, i, n = Monthly weight or mass of calcined
byproducts or waste sold (such as lime kiln dust, LKD) for lime type
i in calendar month n (tons).
Ewaste, i = Annual CO2 emissions for calcined
lime byproduct or waste type i that is not sold (metric tons
CO2) from Equation S-3 of this section.
* * * * *
b = Number of calcined byproducts or wastes that are sold.
z = Number of calcined byproducts or wastes that are not sold.
* * * * *
0
36. Section 98.194 is amended by:
0
a. Revising paragraph (a).
0
b. Revising paragraph (b).
0
c. Revising paragraph (c) introductory text.
Sec. 98.194 Monitoring and QA/QC requirements.
(a) You must determine the total quantity of each type of lime
product that is produced and each calcined byproduct or waste (such as
lime kiln dust) that is sold. The quantities of each should be directly
measured monthly with the same plant instruments used for accounting
purposes, including but not limited to, calibrated weigh feeders, rail
or truck scales, and barge measurements. The direct measurements of
each lime product shall be reconciled annually with the difference in
the beginning of and end of year inventories for these products, when
measurements represent lime sold.
(b) You must determine the annual quantity of each calcined
byproduct or waste generated that is not sold by either direct
measurement using the same instruments identified in paragraph (a) of
this section or by using a calcined byproduct or waste generation rate.
(c) You must determine the chemical composition (percent total CaO
and percent total MgO) of each type of lime product that is produced
and each type of calcined byproduct or waste sold according to
paragraph (c)(1) or (2) of this section. You must determine the
chemical composition of each type of lime product that is produced and
each type of calcined byproduct or waste sold on a monthly basis. You
must determine the chemical composition for each type of calcined
byproduct or waste that is not sold on an annual basis.
* * * * *
0
37. Section 98.195 is amended by revising paragraph (a).
Sec. 98.195 Procedures for estimating missing data.
* * * * *
(a) For each missing value of the quantity of lime produced (by
lime type), and quantity of calcined byproduct or waste produced and
sold, the substitute data value shall be the best available estimate
based on all available process data or data used for accounting
purposes.
* * * * *
0
38. Section 98.196 is amended by revising paragraphs (a)(1), (a)(2),
(a)(4), (a)(5), (a)(7), (b)(1) through (b)(6), (b)(9), (b)(10),
(b)(11), and (b)(14) to read as follows:
Sec. 98.196 Data reporting requirements.
* * * * *
(a) * * *
(1) Method used to determine the quantity of lime that is produced
and quantity of lime that is sold.
(2) Method used to determine the quantity of calcined lime
byproduct or waste sold.
* * * * *
(4) Beginning and end of year inventories for calcined lime
byproducts or wastes sold, by type.
(5) Annual amount of calcined lime byproduct or waste sold, by type
(tons).
* * * * *
(7) Annual amount of calcined lime byproduct or waste that is not
sold, by type (tons).
* * * * *
(b) * * *
(1) Annual CO2 process emissions from all lime kilns
combined (metric tons).
(2) Monthly emission factors (metric ton CO2/ton lime
product) for each lime product type produced.
(3) Monthly emission factors for each calcined byproduct or waste
by lime type that is sold.
(4) Standard method used (ASTM or NLA testing method) to determine
chemical compositions of each lime type produced and each calcined lime
byproduct or waste type.
(5) Monthly results of chemical composition analysis of each type
of lime product produced and calcined byproduct or waste sold.
(6) Annual results of chemical composition analysis of each type of
lime byproduct or waste that is not sold.
* * * * *
(9) Method used to determine the quantity of calcined lime
byproduct or waste sold.
(10) Monthly amount of calcined lime byproduct or waste sold, by
type (tons).
(11) Annual amount of calcined lime byproduct or waste that is not
sold, by type (tons).
* * * * *
(14) Beginning and end of year inventories for calcined lime
byproducts or wastes sold.
* * * * *
Subpart V--[AMENDED]
0
39. Section 98.222 is amended by revising paragraph (a) to read as
follows:
Sec. 98.222 GHGs to report.
(a) You must report N2O process emissions from each
nitric acid train as required by this subpart.
* * * * *
0
40. Section 98.223 is amended by:
0
a. Revising paragraphs (b) introductory text, (b)(1), (b)(3), (d)
introductory text, and (e).
0
b. Revising parameters ``EN2Ot'', ``Pt'', ``DF'',
and ``AF'' of Equation V-3a.
0
c. Revising paragraph (g)(2) introductory text.
0
d. Revising parameters ``EN2Ot'', ``EFN2O, t'',
``Pt'', ``DF1'', ``AF1'',
``DF2'', ``AF2'', ``DFN'', and
``AFN'' of Equation V-3b.
0
e. Revising paragraph (g)(3) introductory text.
0
f. Revising parameters ``EN2Ot'', ``EFN2O, t'',
``Pt'', ``DFN'', ``AFN'', and
``FCN'' of Equation V-3c.
0
g. Revising parameter ``EN2Ot'' of Equation V-3d.
0
h. Revising paragraph (i).
Sec. 98.223 Calculating GHG emissions.
* * * * *
(b) You must conduct an annual performance test for each nitric
acid train according to paragraphs (b)(1) through (b)(3) of this
section.
(1) You must conduct the performance test at the absorber tail gas
vent, referred to as the test point, for each nitric acid train
according to Sec. 98.224(b) through (f). If multiple nitric acid
trains exhaust to a common abatement technology and/or emission point,
you must sample each process in the ducts before the emissions are
combined, sample each process when only one process is operating, or
sample the combined emissions when multiple processes are operating and
base the site-specific emission factor on the combined production rate
of the multiple nitric acid trains.
* * * * *
(3) You must measure the production rate during the performance
test and
[[Page 19857]]
calculate the production rate for the test period in tons (100 percent
acid basis) per hour.
* * * * *
(d) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'', you must determine the destruction
efficiency for each N2O abatement technology ``N'' according
to paragraphs (d)(1), (d)(2), or (d)(3) of this section.
* * * * *
(e) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'', you must determine the annual amount of
nitric acid produced on nitric acid train ``t'' while N2O
abatement technology ``N'' is operating according to Sec. 98.224(f).
Then you must calculate the abatement utilization factor for each
N2O abatement technology ``N'' for each nitric acid train
``t'' according to Equation V-2 of this section.
* * * * *
(g) * * *
(1) * * *
* * * * *
EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3a (metric tons).
* * * * *
Pt = Annual nitric acid production from nitric acid train
``t'' (ton acid produced, 100 percent acid basis).
DF = Destruction efficiency of N2O abatement technology N
that is used on nitric acid train ``t'' (decimal fraction of
N2O removed from vent stream).
AF = Abatement utilization factor of N2O abatement
technology ``N'' for nitric acid train ``t'' (decimal fraction of
annual production during which abatement technology is operating).
* * * * *
(2) If multiple N2O abatement technologies are located
in series after your test point, you must use the emissions factor
(determined in Equation V-1 of this section), the destruction
efficiency (determined in paragraph (d) of this section), the annual
nitric acid production (determined in paragraph (i) of this section),
and the abatement utilization factor (determined in paragraph (e) of
this section), according to Equation V-3b of this section:
* * * * *
EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3b (metric tons).
EFN2O, t = N2O emissions factor for nitric
acid train ``t'' (lb N2O/ton nitric acid produced).
Pt = Annual nitric acid produced from nitric acid train
``t'' (ton acid produced, 100 percent acid basis).
DF1 = Destruction efficiency of N2O abatement
technology 1 (decimal fraction of N2O removed from vent
stream).
AF1 = Abatement utilization factor of N2O
abatement technology 1 (decimal fraction of time that abatement
technology 1 is operating).
DF2 = Destruction efficiency of N2O abatement
technology 2 (decimal fraction of N2O removed from vent
stream).
AF2 = Abatement utilization factor of N2O
abatement technology 2 (decimal fraction of time that abatement
technology 2 is operating).
DFN = Destruction efficiency of N2O abatement
technology N (decimal fraction of N2O removed from vent
stream).
AFN = Abatement utilization factor of N2O
abatement technology N (decimal fraction of time that abatement
technology N is operating).
* * * * *
(3) If multiple N2O abatement technologies are located
in parallel after your test point, you must use the emissions factor
(determined in Equation V-1 of this section), the destruction
efficiency (determined in paragraph (d) of this section), the annual
nitric acid production (determined in paragraph (i) of this section),
and the abatement utilization factor (determined in paragraph (e) of
this section), according to Equation V-3c of this section:
* * * * *
EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3c (metric tons).
EFN2O, t = N2O emissions factor for nitric
acid train ``t'' (lb N2O/ton nitric acid produced).
Pt = Annual nitric acid produced from nitric acid train
``t'' (ton acid produced, 100 percent acid basis).
DFN = Destruction efficiency of N2O abatement
technology ``N'' (decimal fraction of N2O removed from
vent stream).
AFN = Abatement utilization factor of N2O
abatement technology ``N'' (decimal fraction of time that abatement
technology ``N'' is operating).
FCN = Fraction control factor of N2O abatement
technology ``N'' (decimal fraction of total emissions from nitric
acid train ``t'' that are sent to abatement technology ``N'').
* * * * *
(4) * * *
* * * * *
EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3d (metric tons).
* * * * *
(i) You must determine the total annual amount of nitric acid
produced on each nitric acid train ``t'' (tons acid produced, 100
percent acid basis), according to Sec. 98.224(f).
0
41. Section 98.224 is amended by revising paragraphs (c) introductory
text, (e), and (f) to read as follows:
Sec. 98.224 Monitoring and QA/QC requirements.
* * * * *
(c) You must determine the production rate(s) (100 percent acid
basis) from each nitric acid train during the performance test
according to paragraphs (c)(1) or (c)(2) of this section.
* * * * *
(e) You must determine the total monthly amount of nitric acid
produced. You must also determine the monthly amount of nitric acid
produced while N2O abatement technology is operating from
each nitric acid train. These monthly amounts are determined according
to the methods in paragraphs (c)(1) or (2) of this section.
(f) You must determine the annual amount of nitric acid produced.
You must also determine the annual amount of nitric acid produced while
N2O abatement technology is operating for each nitric acid
train. These annual amounts are determined by summing the respective
monthly nitric acid quantities determined in paragraph (e) of this
section.
0
42. Section 98.226 is amended by:
0
a. Revising paragraph (a) and paragraph (n) introductory text.
0
b. Adding and reserving paragraph (o).
0
c. Revising paragraph (p).
Sec. 98.226 Data reporting requirements.
* * * * *
(a) Nitric Acid train identification number.
* * * * *
(n) If you requested Administrator approval for an alternative
method of determining N2O emissions under Sec.
98.223(a)(2), each annual report must also contain the information
specified in paragraphs (n)(1) through (n)(4) of this section for each
nitric acid production facility.
* * * * *
(o) [Reserved]
(p) Fraction control factor for each abatement technology (percent
of total emissions from the nitric acid train that are sent to the
abatement technology) if Equation V-3c is used.
Subpart X--[AMENDED]
0
43. Section 98.242 is amended by revising paragraph (b)(2) to read as
follows:
Sec. 98.242 GHGs to report.
* * * * *
(b) * * *
(2) If you comply with Sec. 98.243(c), report CO2,
CH4, and N2O combustion
[[Page 19858]]
emissions under subpart C of this part (General Stationary Fuel
Combustion Sources) by following the requirements of subpart C for all
fuels, except emissions from burning petrochemical process off-gas in
any combustion unit are not to be reported under subpart C of this
part. Determine the applicable Tier in subpart C of this part (General
Stationary Fuel Combustion Sources) based on the maximum rated heat
input capacity of the stationary combustion source.
* * * * *
0
44. Section 98.243 is amended by:
0
a. Revising paragraph (b).
0
b. Revising paragraphs (c)(3) and (c)(4).
0
c. Revising the parameters ``Cg'',
``(Fgf)i, n'',
``(Pgp)i, n'', and
``(MWp)i'' of Equation X-1.
0
d. Removing the parameter ``(MWf)I'' of Equation
X-1 and adding parameter ``(MWf)i, n'' in its
place.
0
e. Revising paragraph (d)(3)(i).
Sec. 98.243 Calculating GHG emissions.
* * * * *
(b) Continuous emission monitoring system (CEMS). Route all process
vent emissions and emissions from stationary combustion units that burn
any amount of process off-gas to one or more stacks and determine GHG
emissions as specified in paragraphs (b)(1) through (3) of this
section.
(1) Determine CO2 emissions from each stack (except
flare stacks) according to the Tier 4 Calculation Methodology
requirements in subpart C of this part.
(2) For each stack (except flare stacks) that includes emissions
from combustion of petrochemical process off-gas, calculate
CH4 and N2O emissions in accordance with subpart
C of this part (use Equation C-10 and the ``fuel gas'' emission factors
in Table C-2 of subpart C of this part.
(3) For each flare, calculate CO2, CH4, and
N2O emissions using the methodology specified in Sec.
98.253(b)(1) through (b)(3).
(c) * * *
(3) Collect a sample of each feedstock and product at least once
per month and determine the carbon content of each sample according to
the procedures of Sec. 98.244(b)(4). If multiple valid carbon content
measurements are made during the monthly measurement period, average
them arithmetically. However, if a particular liquid or solid feedstock
is delivered in lots, and if multiple deliveries of the same feedstock
are received from the same supply source in a given calendar month,
only one representative sample is required. Alternatively, you may use
the results of analyses conducted by a feedstock supplier, or product
customer, provided the sampling and analysis is conducted at least once
per month using any of the procedures specified in Sec. 98.244(b)(4).
(4) If you determine that the monthly average concentration of a
specific compound in a feedstock or product is greater than 99.5
percent by volume or mass, then as an alternative to the sampling and
analysis specified in paragraph (c)(3) of this section, you may
determine carbon content in accordance with paragraphs (c)(4)(i)
through (iii) of this section.
(i) Calculate the carbon content assuming 100 percent of that
feedstock or product is the specific compound.
(ii) Maintain records of any determination made in accordance with
this paragraph (c)(4) along with all supporting data, calculations, and
other information.
(iii) Reevaluate determinations made under this paragraph (c)(4)
after any process change that affects the feedstock or product
composition. Keep records of the process change and the corresponding
composition determinations. If the feedstock or product composition
changes so that the average monthly concentration falls below 99.5
percent, you are no longer permitted to use this alternative method.
(5) * * *
(i) * * *
* * * * *
Cg = Annual net contribution to calculated emissions from
carbon (C) in gaseous materials, including streams containing
CO2 recovered for sale or use in another process (kg/yr).
(Fgf)i,n = Volume or mass of gaseous feedstock
i introduced in month ``n'' (scf or kg). If you measure mass, the
term (MWf)i/MVC is replaced with ``1''.
* * * * *
(MWf)i,n = Molecular weight of gaseous
feedstock i in month ``n''(kg/kg-mole).
* * * * *
(Pgp)i,n = Volume or mass of gaseous product i
produced in month ``n'' (scf or kg). If you measure mass, the term
(MWp)i/MVC is replaced with ``1''.
* * * * *
(MWp)i,n = Molecular weight of gaseous product
i in month ``n'' (kg/kg-mole).
* * * * *
(d) * * *
(3) * * *
(i) For all gaseous fuels that contain ethylene process off-gas,
use the emission factors for ``Fuel Gas'' in Table C-2 of subpart C of
this part (General Stationary Fuel Combustion Sources).
* * * * *
0
45. Section 98.244 is amended by:
0
a. Revising the last sentence of paragraph (b)(4) introductory text,
and paragraphs (b)(4)(xiii), (b)(4)(xiv), and (b)(4)(xv)(A).
0
b. Adding paragraph (c).
Sec. 98.244 Monitoring and QA/QC requirements.
* * * * *
(b) * * *
(4) * * * Analyses conducted in accordance with methods specified
in paragraphs (b)(4)(i) through (b)(4)(xv) of this section may be
performed by the owner or operator, by an independent laboratory, by
the supplier of a feedstock, or by a product customer.
* * * * *
(xiii) The results of chromatographic analysis of a feedstock or
product, provided that the chromatograph is operated, maintained, and
calibrated according to the manufacturer's instructions.
(xiv) The results of mass spectrometer analysis of a feedstock or
product, provided that the mass spectrometer is operated, maintained,
and calibrated according to the manufacturer's instructions.
(xv) * * *
(A) An industry standard practice or a method published by a
consensus-based standards organization if such a method exists for
carbon black feedstock oils and carbon black products. Consensus-based
standards organizations include, but are not limited to, the following:
ASTM International (100 Barr Harbor Drive, P.O. Box CB700, West
Conshohocken, Pennsylvania 19428-B2959, (800) 262-1373, http://www.astm.org), the American National Standards Institute (ANSI, 1819 L
Street, NW., 6th floor, Washington, DC 20036, (202) 293-8020, http://www.ansi.org), the American Gas Association (AGA, 400 North Capitol
Street, NW., 4th Floor, Washington, DC 20001, (202) 824-7000, http://www.aga.org), the American Society of Mechanical Engineers (ASME, Three
Park Avenue, New York, NY 10016-5990, (800) 843-2763, http://www.asme.org), the American Petroleum Institute (API, 1220 L Street,
NW., Washington, DC 20005-4070, (202) 682-8000, http://www.api.org),
and the North American Energy Standards Board (NAESB, 801 Travis
Street, Suite 1675, Houston, TX 77002, (713) 356-0060, http://www.naesb.org). The method(s) used shall be documented in the
monitoring plan required under Sec. 98.3(g)(5).
* * * * *
[[Page 19859]]
(c) If you comply with Sec. 98.243(b) or (d), conduct monitoring
and QA/QC for flares in accordance with Sec. 98.254.
0
46. Section 98.245 is revised to read as follows:
Sec. 98.245 Procedures for estimating missing data.
For missing feedstock and product flow rates, use the same
procedures as for missing fuel usage as specified in Sec. 98.35(b)(2).
For missing feedstock and product carbon contents and missing molecular
weights for gaseous feedstocks and products, use the same procedures as
for missing carbon contents and missing molecular weights for fuels as
specified in Sec. 98.35(b)(1). For missing flare data, follow the
procedures in Sec. 98.255(b) and (c).
0
47. Section 98.246 is amended by:
0
a. Revising paragraphs (a)(6), (a)(8), (a)(9), (a)(11) introductory
text, (b)(2), (b)(4), and (b)(5).
0
b. Removing and reserving paragraphs (b)(5)(i) through (iv), and
(b)(6).
0
c. Revising paragraph (c)(4).
Sec. 98.246 Data reporting requirements.
* * * * *
(a) * * *
(6) For each feedstock and product, provide the information
specified in paragraphs (a)(6)(i) through (a)(6)(iii) of this section.
(i) Name of each method used to determine carbon content or
molecular weight in accordance with 98.244(b)(4);
(ii) Description of each type of device (e.g., flow meter, weighing
device) used to determine flow or mass in accordance 98.244(b)(1)
through (3).
(iii) Identification of each method (i.e., method number, title, or
other description) used to determine flow or mass in accordance with
98.244(b)(1) through (3).
* * * * *
(8) Identification of each combustion unit that burned both process
off-gas and supplemental fuel, including combustion units that are not
part of the petrochemical process unit.
(9) If you comply with the alternative to sampling and analysis
specified in Sec. 98.243(c)(4), the number of days during which off-
specification product was produced, and if applicable, the date of any
process change that reduced the composition to less than 99.5 percent.
* * * * *
(11) If you determine carbon content or composition of a feedstock
or product using a method under Sec. 98.244(b)(4)(xv)(B), report the
information listed in paragraphs (a)(11)(i) through (a)(11)(iii) of
this section. Include the information in paragraph (a)(11)(i) of this
section in each annual report. Include the information in paragraphs
(a)(11)(ii) and (a)(11)(iii) of this section only in the first
applicable annual report, and provide any changes to this information
in subsequent annual reports.
* * * * *
(b) * * *
(2) For CEMS used on stacks that include emissions from stationary
combustion units that burn any amount of off-gas from the petrochemical
process, report the relevant information required under Sec.
98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology.
Sections Sec. 98.36(c)(2)(ii) and (c)(2)(ix) do not apply for the
purposes of this subpart.
(3) For CEMS used on stacks that do not include emissions from
stationary combustion units, report the information required under
Sec. 98.36(b)(6), (b)(7), and Sec. 98.36(e)(2)(vi).
(4) For each CEMS monitoring location that meets the conditions in
paragraph (b)(2) or (3) of this section, provide an estimate based on
engineering judgment of the fraction of the total CO2
emissions that is attributable to the petrochemical process unit.
(5) For each CEMS monitoring location that meets the conditions in
paragraph (b)(2) of this section, report the CH4 and
N2O emissions expressed in metric tons of each gas. For each
CEMS monitoring location provide an estimate based on engineering
judgment of the fraction of the total CH4 and N2O
emissions that is attributable to combustion of off-gas from the
petrochemical process unit.
(i) [Reserved]
(ii)[Reserved]
(iii) [Reserved]
(iv)[Reserved]
(6) [Reserved]
* * * * *
(c) * * *
(4) Name and annual quantity of each feedstock (metric tons).
* * * * *
48. Section 98.247 is amended by revising paragraphs (b)
introductory text and (b)(2) to read as follows:
Sec. 98.247 Records that must be retained.
* * * * *
(b) If you comply with the mass balance methodology in Sec.
98.243(c), then you must retain records of the information listed in
paragraphs (b)(1) through (b)(4) of this section.
* * * * *
(2) Start and end times for time periods when off-specification
product is produced, if you comply with the alternative methodology in
Sec. 98.243(c)(4) for determining carbon content of product.
* * * * *
0
49. Section 98.248 is amended by revising the definition of ``Product''
to read as follows:
Sec. 98.248 Definitions.
* * * * *
Product, as used in Sec. 98.243, means each of the following
carbon-containing outputs from a process: The petrochemical, recovered
byproducts, and liquid organic wastes that are not combusted onsite.
Product does not include process vent emissions, fugitive emissions, or
wastewater.
Subpart Y--[AMENDED]
0
50. Section 98.252 is amended by revising the parenthetical phrase
preceding the last two sentences in paragraph (a) introductory text,
and revising paragraph (i), to read as follows:
Sec. 98.252 GHGs to report.
* * * * *
(a) * * * (Use the default CH4 and N2O
emission factors for ``Fuel Gas'' in Table C-2 of this part. For Tier
3, use either the default high heat value for fuel gas in Table C-1 of
subpart C of this part or a calculated HHV, as allowed in Equation C-8
of subpart C of this part.) * * *
* * * * *
(i) CO2 emissions from non-merchant hydrogen production
process units (not including hydrogen produced from catalytic reforming
units) following the calculation methodologies, monitoring and QA/QC
methods, missing data procedures, reporting requirements, and
recordkeeping requirements of subpart P of this part.
0
51. Section 98.253 is amended by:
0
a. Revising the parameter ``EmFCH4'' to Equation Y-4 and
``EmFN2O'' to Equation Y-5.
0
b. Revising paragraphs (f)(2), (f)(3), and (f)(4) introductory text.
0
c. Revising parameters ``FSG'' and ``MFc'' to
Equation Y-12.
0
d. Revising paragraphs (j) introductory text, (k) introductory text,
and (m) introductory text.
Sec. 98.253 Calculating GHG emissions.
* * * * *
(b) * * *
(2) * * *
* * * * *
EmFCH4 = Default CH4 emission factor for
``Fuel Gas'' from Table C-2 of subpart C
[[Page 19860]]
of this part (General Stationary Fuel Combustion Sources) (kg
CH4/MMBtu).
* * * * *
(3) * * *
* * * * *
EmFN2O = Default N2O emission factor for
``Fuel Gas'' from Table C-2 of subpart C of this part (General
Stationary Fuel Combustion Sources) (kg N2O/MMBtu).
* * * * *
(f) * * *
(2) Flow measurement. If you have a continuous flow monitor on the
sour gas feed to the sulfur recovery plant or the sour gas feed sent
for off-site sulfur recovery, you must use the measured flow rates when
the monitor is operational to calculate the sour gas flow rate. If you
do not have a continuous flow monitor on the sour gas feed to the
sulfur recovery plant or the sour gas feed sent for off-site sulfur
recovery, you must use engineering calculations, company records, or
similar estimates of volumetric sour gas flow.
(3) Carbon content. If you have a continuous gas composition
monitor capable of measuring carbon content on the sour gas feed to the
sulfur recovery plant or the sour gas feed sent for off-site for sulfur
recovery, or if you monitor gas composition for carbon content on a
routine basis, you must use the measured carbon content value.
Alternatively, you may develop a site-specific carbon content factor
using limited measurement data or engineering estimates or use the
default factor of 0.20.
(4) Calculate the CO2 emissions from each on-site sulfur
recovery plant and for sour gas sent off-site for sulfur recovery using
Equation Y-12 of this section.
* * * * *
FSG = Volumetric flow rate of sour gas (including sour
water stripper gas) fed to the sulfur recovery plant or the sour gas
feed sent for off-site for sulfur recovery (scf/year).
* * * * *
MFC = Mole fraction of carbon in the sour gas fed to the
sulfur recovery plant or the four gas feed sent for off-site for
sulfur recovery (kg-mole C/kg-mole gas); default = 0.20.
* * * * *
(j) For each process vent not covered in paragraphs (a) through (i)
of this section that can reasonably be expected to contain greater than
2 percent by volume CO2 or greater than 0.5 percent by
volume of CH4 or greater than 0.01 percent by volume (100
parts per million) of N2O, calculate GHG emissions using the
Equation Y-19 of this section. You must also use Equation Y-19 of this
section to calculate CH4 emissions for catalytic reforming
unit depressurization and purge vents when methane is used as the purge
gas, CH4 emissions if you elected to use the method in
paragraph (i)(1) of this section, and CO2 and/or
CH4 emissions, as applicable, if you elected this method as
an alternative to the methods in paragraphs (f), (h), or (k) of this
section.
* * * * *
(k) For uncontrolled blowdown systems, you must calculate
CH4 emissions either using the methods for process vents in
paragraph (j) of this section regardless of the CH4
concentration or using Equation Y-20 of this section. Blowdown systems
where the uncondensed gas stream is routed to a flare or similar
control device is considered to be controlled and is not required to
estimate emissions under this paragraph (k).
* * * * *
(m) For storage tanks, except as provided in paragraph (m)(3) of
this section, calculate CH4 emissions using the applicable
methods in paragraphs (m)(1) and (m)(2) of this section.
* * * * *
0
52. Section 98.256 is amended by:
0
a. Revising paragraphs (f)(6), (h) introductory text, (h)(2), (h)(3),
(h)(4), (h)(5), and (h)(6).
0
b. Adding paragraph (j)(10).
0
c. Revising paragraph (k)(4).
0
d. Adding paragraph (k)(6).
0
e. Revising paragraph (o)(4)(vi).
0
f. Removing and reserving paragraphs (o)(5) through (7).
Sec. 98.256 Data reporting requirements.
* * * * *
(f) * * *
(6) If you use a CEMS, the relevant information required under
Sec. 98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS (unadjusted to remove
CO2 combustion emissions associated with additional units,
if present) and the process CO2 emissions as calculated
according to Sec. 98.253(c)(1)(ii). Report the CO2 annual
emissions associated with sources other than those from the coke burn-
off in accordance with the applicable subpart (e.g., subpart C of this
part in the case of a CO boiler).
* * * * *
(h) For on-site sulfur recovery plants and for emissions from sour
gas sent off-site for sulfur recovery, the owner and operator shall
report:
* * * * *
(2) For each on-site sulfur recovery plant, the maximum rated
throughput (metric tons sulfur produced/stream day), a description of
the type of sulfur recovery plant, and an indication of the method used
to calculate CO2 annual emissions for the sulfur recovery
plant (e.g., CO2 CEMS, Equation Y-12, or process vent method
in Sec. 98.253(j)).
(3) The calculated CO2 annual emissions for each on-site
sulfur recovery plant, expressed in metric tons. The calculated annual
CO2 emissions from sour gas sent off-site for sulfur
recovery, expressed in metric tons.
(4) If you use Equation Y-12 of this subpart, the annual volumetric
flow to the on-site and off-site sulfur recovery plant (in scf/year),
the molar volume conversion factor (in scf/kg-mole), and the annual
average mole fraction of carbon in the sour gas (in kg-mole C/kg-mole
gas).
(5) If you recycle tail gas to the front of an on-site sulfur
recovery plant, indicate whether the recycled flow rate and carbon
content are included in the measured data under Sec. 98.253(f)(2) and
(3). Indicate whether a correction for CO2 emissions in the
tail gas was used in Equation Y-12. If so, then report the value of the
correction, the annual volume of recycled tail gas (in scf/year) and
the annual average mole fraction of carbon in the tail gas (in kg-mole
C/kg-mole gas). Indicate whether you used the default (95%) or a unit
specific correction, and if a unit specific correction is used, report
the approach used.
(6) If you use a CEMS, the relevant information required under
Sec. 98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS and the annual process
CO2 emissions calculated according to Sec. 98.253(f)(1).
Report the CO2 annual emissions associated with fuel
combustion in accordance with subpart C of this part (General
Stationary Fuel Combustion Sources).
* * * * *
(j) * * *
(10) If you use Equation Y-19 of this subpart, the relevant
information required under paragraph (l)(5) of this section.
(k) * * *
(4) For each set of coking drums that are the same dimensions: The
number of coking drums in the set, the height and diameter of the coke
drums (in feet), the cumulative number of vessel openings for all
delayed coking drums in the set, the typical venting pressure (in
psig), void fraction (in cf gas/cf of vessel), and the mole fraction of
methane in coking gas (in kg-mole CH4/kg-mole gas, wet
basis).
* * * * *
[[Page 19861]]
(6) If you use Equation Y-19 of this subpart, the relevant
information required under paragraph (l)(5) of this section for each
set of coke drums or vessels of the same size.
* * * * *
(o) * * *
(4) * * *
(vi) If you did not use Equation Y-23, the tank-specific methane
composition data and the annual gas generation volume (scf/yr) used to
estimate the cumulative CH4 emissions for storage tanks used
to process unstabilized crude oil.
(5) [Reserved]
(6) [Reserved]
(7) [Reserved]
* * * * *
Subpart Z--[AMENDED]
0
53. Section 98.263 is amended by revising paragraph (b)(1)(ii)
introductory text and the parameter ``CO2n,i'' of Equation
Z-1b to read as follows:
Sec. 98.263 Calculating GHG emissions.
* * * * *
(b) * * *
(1) * * *
(ii) If your process measurement provides the CO2
content directly as an output, calculate and report the process
CO2 emissions from each wet-process phosphoric acid process
line using Equation Z-1b of this section:
* * * * *
CO2n,i = Carbon dioxide content of a grab sample batch of
phosphate rock by origin i obtained during month n (percent by
weight, expressed as a decimal fraction).
* * * * *
0
54. Section 98.264 is amended by revising paragraphs (a) and (b) to
read as follows:
Sec. 98.264 Monitoring and QA/QC requirements.
(a) You must obtain a monthly grab sample of phosphate rock
directly from the rock being fed to the process line before it enters
the mill using one of the following methods. You may conduct the
representative bulk sampling using a method published by a consensus
standards organization, or you may use industry consensus standard
practice methods, including but not limited to the Phosphate Mining
States Methods Used and Adopted by the Association of Fertilizer and
Phosphate Chemists (AFPC). If phosphate rock is obtained from more than
one origin in a month, you must obtain a sample from each origin of
rock or obtain a composite representative sample.
(b) You must determine the carbon dioxide or inorganic carbon
content of each monthly grab sample of phosphate rock (consumed in the
production of phosphoric acid). You may use a method published by a
consensus standards organization, or you may use industry consensus
standard practice methods, including but not limited to the Phosphate
Mining States Methods Used and Adopted by AFPC.
* * * * *
0
55. Section 98.265 is amended by adding introductory text and revising
paragraph (a) to read as follows:
Sec. 98.265 Procedures for estimating missing data.
A complete record of all measured parameters used in the GHG
emissions calculations is required. Therefore, whenever a quality-
assured value of a required parameter is unavailable, a substitute data
value for the missing parameter must be used in the calculations as
specified in paragraphs (a) and (b) of this section.
(a) For each missing value of the inorganic carbon content or
CO2 content of phosphate rock (by origin), you must use the
appropriate default factor provided in Table Z-1 of this subpart.
Alternatively, you must determine a substitute data value by
calculating the arithmetic average of the quality-assured values of
inorganic carbon contents or CO2 contents of phosphate rock
of origin i (see Equation Z-1a or Z-1b of this subpart) from samples
immediately preceding and immediately following the missing data
incident. If no quality-assured data on inorganic carbon contents or
CO2 contents of phosphate rock of origin i are available
prior to the missing data incident, the substitute data value shall be
the first quality-assured value for inorganic carbon contents or
CO2 contents for phosphate rock of origin i obtained after
the missing data period.
* * * * *
0
56. Section 98.266 is amended by revising paragraphs (a), (b), (d),
(f)(5), (f)(6), and (f)(8) to read as follows:
Sec. 98.266 Data reporting requirements.
* * * * *
(a) Annual phosphoric acid production, by origin of the phosphate
rock (tons).
(b) Annual phosphoric acid production capacity (tons).
* * * * *
(d) Annual phosphate rock consumption from monthly measurement
records by origin (tons).
* * * * *
(f) * * *
(5) Monthly inorganic carbon content of phosphate rock for each
wet-process phosphoric acid process line for which Equation Z-1a is
used (percent by weight, expressed as a decimal fraction), or
CO2 content (percent by weight, expressed as a decimal
fraction) for which Equation Z-1b is used.
(6) Monthly mass of phosphate rock consumed, by origin, in
production for each wet-process phosphoric acid process line (tons).
* * * * *
(8) Number of times missing data procedures were used to estimate
phosphate rock consumption (months), inorganic carbon contents of the
phosphate rock (months), and CO2 contents of the phosphate
rock (months).
* * * * *
0
57. Section 98.267 is amended by revising paragraphs (a) and (c) to
read as follows:
Sec. 98.267 Records that must be retained.
* * * * *
(a) Monthly mass of phosphate rock consumed by origin (tons).
* * * * *
(c) Documentation of the procedures used to ensure the accuracy of
monthly phosphate rock consumption by origin.
Subpart AA--[AMENDED]
0
58. Section 98.273 is amended by revising paragraph (a)(3) introductory
text and the parameter ``(EF)'' of Equation AA-1 to read as follows:
Sec. 98.273 Calculating GHG emissions.
(a) * * *
(3) Calculate biogenic CO2 emissions and emissions of
CH4 and N2O from biomass using measured
quantities of spent liquor solids fired, site-specific HHV, and default
emissions factors, according to Equation AA-1 of this section:
* * * * *
(EF) = Default emission factor for CO2, CH4,
or N2O, from Table AA-1 of this subpart (kg
CO2, CH4, or N2O per mmBtu).
* * * * *
0
59. Section 98.276 is amended by revising paragraphs (e) and (k) to
read as follows:
Sec. 98.276 Data reporting requirements.
* * * * *
(e) The default emission factor for CO2, CH4,
or N2O, used in Equation AA-1 of this subpart (kg
CO2, CH4, or N2O per mmBtu).
* * * * *
(k) Annual production of pulp and/or paper products produced
(metric tons) as follows:
(1) Report the total annual production of unbleached virgin pulp
produced
[[Page 19862]]
onsite during the reporting year in air-dried metric tons per year.
This total annual production value is the sum of all kraft,
semichemical, soda, and sulfite pulp produced onsite, prior to
bleaching, through all virgin pulping lines.
(i) Do not include secondary fiber repulped for paper production in
the virgin pulp production total.
(ii) You must report a positive (non-zero) value for pulp
production unless your pulp mill did not operate during the reporting
year.
(2) Report the total annual production of paper products exiting
the paper machine(s), prior to application of any off-machine coatings,
in air-dried metric tons per year. If you operate multiple paper
machines, report the sum (total) of the air-dried metric tons of paper
produced during the reporting year for all paper machines at the mill.
0
60. Tables AA-1 and AA-2 are revised to read as follows:
Table AA-1 to Subpart AA of Part 98--Kraft Pulping Liquor Emissions Factors for Biomass-Based CO2, CH4, and N2O
----------------------------------------------------------------------------------------------------------------
Biomass-based emissions factors (kg/mmBtu HHV)
Wood furnish -----------------------------------------------
CO2a CH4 N2O
----------------------------------------------------------------------------------------------------------------
North American Softwood......................................... 94.4 0.0019 0.00042
North American Hardwood......................................... 93.7 0.0019 0.00042
Bagasse......................................................... 95.5 0.0019 0.00042
Bamboo.......................................................... 93.7 0.0019 0.00042
Straw........................................................... 95.1 0.0019 0.00042
----------------------------------------------------------------------------------------------------------------
a Includes emissions from both the recovery furnace and pulp mill lime kiln.
Table AA-2 to Subpart AA of Part 98--Kraft Lime Kiln and Calciner Emissions Factors for CH4 and N2O
----------------------------------------------------------------------------------------------------------------
Fossil fuel-based emissions factors (kg/mmBtu HHV)
------------------------------------------------------------------------------
Fuel Kraft lime kilns Kraft calciners
------------------------------------------------------------------------------
CH4 N2O CH4 N2O
----------------------------------------------------------------------------------------------------------------
Residual Oil (any type).......... 0.0027............. 0 0.0027............. 0.0003.
Distillate Oil (any type)........ 0.0027............. 0 0.0027............. 0.0004.
Natural Gas...................... 0.0027............. 0 0.0027............. 0.0001.
Biogas........................... 0.0027............. 0 0.0027............. 0.0001.
Petroleum coke................... 0.0027............. 0 NA a............... NA a.
Other Fuels...................... See Table C-2...... 0 See Table C-2...... See Table C-2.
----------------------------------------------------------------------------------------------------------------
a Emission factors for kraft calciners are not available.
Subpart BB--[AMENDED]
0
61. Section 98.282 is amended by revising paragraph (a) to read as
follows:
Sec. 98.282 GHGs to report.
* * * * *
(a) CO2 process emissions from all silicon carbide
process units or furnaces combined.
* * * * *
0
62. Section 98.283 is amended by:
0
a. Revising the introductory text.
0
b. Revising paragraphs (a), (b) introductory text, and (b)(2)
introductory text.
0
c. Revising the parameter ``Tn'' in Equation BB-2.
0
d. Removing paragraph (d).
Sec. 98.283 Calculating GHG emissions.
You must calculate and report the combined annual process
CO2 emissions from all silicon carbide process units and
production furnaces using the procedures in either paragraph (a) or (b)
of this section.
(a) Calculate and report under this subpart the combined annual
process CO2 emissions by operating and maintaining CEMS
according to the Tier 4 Calculation Methodology specified in Sec.
98.33(a)(4) and all associated requirements for Tier 4 in subpart C of
this part (General Stationary Fuel Combustion Sources).
(b) Calculate and report under this subpart the combined annual
process CO2 emissions using the procedures in paragraphs
(b)(1) and (b)(2) of this section.
* * * * *
(2) Calculate annual CO2 process emissions from the
silicon carbide production facility according to Equation BB-2 of this
section:
* * * * *
Tn = Petroleum coke consumption in calendar month n
(tons).
* * * * *
0
63. Section 98.286 is amended by revising paragraph (b) introductory
text to read as follows:
Sec. 98.286 Data reporting requirements.
* * * * *
(b) If a CEMS is not used to measure process CO2
emissions, you must report the information in paragraph (b)(1) through
(b)(8) of this section for all silicon carbide process units or
production furnaces combined:
* * * * *
Subpart DD--[AMENDED]
0
64. Section 98.304 is amended by revising paragraphs (c)(1) and (c)(2)
to read as follows:
Sec. 98.304 Monitoring and QA/QC requirements.
* * * * *
(c) * * *
(1) Ensure that cylinders returned to the gas supplier are
consistently weighed on a scale that is certified to be accurate and
precise to within 2 pounds of true weight and is periodically
recalibrated per the manufacturer's specifications. Either measure
residual gas (the amount of gas remaining in returned cylinders) or
have the gas supplier measure it. If the gas supplier weighs the
residual gas, obtain from the gas supplier a detailed monthly
accounting, within 2 pounds, of
[[Page 19863]]
residual gas amounts in the cylinders returned to the gas supplier.
(2) Ensure that cylinders weighed for the beginning and end of year
inventory measurements are weighed on a scale that is certified to be
accurate and precise to within 2 pounds of true weight and is
periodically recalibrated per the manufacturer's specifications. All
scales used to measure quantities that are to be reported under Sec.
98.306 must be calibrated using calibration procedures specified by the
scale manufacturer. Calibration must be performed prior to the first
reporting year. After the initial calibration, recalibration must be
performed at the minimum frequency specified by the manufacturer.
* * * * *
Subpart FF--[AMENDED]
0
65. Section 98.320 is amended by revising paragraphs (b)(1) and (b)(2)
to read as follows:
Sec. 98.320 Definition of the source category.
* * * * *
(b) * * *
(1) Each ventilation system shaft or vent hole, including both
those points where mine ventilation air is emitted and those where it
is sold, used onsite, or otherwise destroyed (including by ventilation
air methane (VAM) oxidizers).
(2) Each degasification system well or gob gas vent hole, including
degasification systems deployed before, during, or after mining
operations are conducted in a mine area. This includes both those wells
and vent holes where coal bed gas is emitted, and those where the gas
is sold, used onsite, or otherwise destroyed (including by flaring).
* * * * *
0
66. Section 98.322 is amended by revising paragraphs (b) and (d) to
read as follows:
Sec. 98.322 GHGs to report.
* * * * *
(b) You must report CH4 destruction from systems where
gas is sold, used onsite, or otherwise destroyed (including by VAM
oxidation and by flaring).
* * * * *
(d) You must report under this subpart the CO2 emissions
from coal mine gas CH4 destruction occurring at the
facility, where the gas is not a fuel input for energy generation or
use (e.g., flaring and VAM oxidation).
* * * * *
0
67. Section 98.323 is amended by:
0
a. Revising parameters ``V'', ``MCF'', ``(fH2O)'', and ``P''
of Equation FF-2.
0
b. Revising paragraphs (a)(2) and (b)(1).
0
c. Revising Equation FF-3 and parameters ``Vi'',
``MCFi'', ``Pi'', and ``(fH2O)'' of
Equation FF-3.
0
d. Removing parameter ``(CH4D)'' of Equation FF-4 and adding
parameter ``(CH4D)i,j'' in its place.
0
e. Revising paragraph (c) introductory text and Equation FF-6.
Sec. 98.323 Calculating GHG emissions.
(a) * * *
* * * * *
V = Volumetric flow rate for the quarter (acfm) based on sampling or
a flow rate meter. If a flow rate meter is used and the meter
automatically corrects to standard temperature and pressure, then
use scfm and replace ``520[deg]R/T x P/1 atm'' with ``1''.
MCF = Moisture correction factor for the measurement period,
volumetric basis.
= 1 when V and C are measured on a dry basis or if both are measured
on a wet basis. = 1-(fH2O) when V is measured on a wet
basis and C is measured on a dry basis. = 1/[1-(fH2O)]
when V is measured on a dry basis and C is measured on a wet basis.
(fH2O) = Moisture content of the methane emitted during
the measurement period, volumetric basis (cubic feet water per cubic
feet emitted gas).
* * * * *
P = Absolute pressure at which flow is measured (atm) for the
quarter. The annual average barometric pressure from the nearest
NOAA weather service station may be used as a default.
* * * * *
(2) Values of V, C, T, P, and (fH2O), if applicable,
must be based on measurements taken at least once each quarter with no
fewer than 6 weeks between measurements. If measurements are taken more
frequently than once per quarter, then use the average value for all
measurements taken. If continuous measurements are taken, then use the
average value over the time period of continuous monitoring.
* * * * *
(b) * * *
[GRAPHIC] [TIFF OMITTED] TP02AP13.003
* * * * *
Vi = Measured volumetric flow rate for the days in the
week when the degasification system is in operation at that
monitoring point, based on sampling or a flow rate meter (acfm). If
a flow rate meter is used and the meter automatically corrects to
standard temperature and pressure, then use scfm and replace
``520[deg]R/Tix Pi/1 atm'' with ``1''.
MCFi = Moisture correction factor for the measurement
period, volumetric basis.
= 1 when Vi and Ci are measured on a dry basis
or if both are measured on a wet basis. = 1-
(fH2O)I when Vi is measured on a
wet basis and Ci is measured on a dry basis. = 1/[1-
(fH2O)i] when Vi is measured on a
dry basis and Ci is measured on a wet basis.
(fH2O) = Moisture content of the CH4 emitted
during the measurement period, volumetric basis (cubic feet water
per cubic feet emitted gas).
* * * * *
Pi = Absolute pressure at which flow is measured (atm).
* * * * *
(1) Values for V, C, T, P, and (fH2O), if applicable,
must be based on measurements taken at least once each calendar week
with at least 3 days between measurements. If measurements are taken
more frequently than once per week, then use the average value for all
measurements taken that week. If continuous measurements are taken,
then use the average values over the time period of continuous
monitoring when the continuous monitoring equipment is properly
functioning.
(2) * * *
* * * * *
(CH4D)i,j = Weekly CH4 liberated
from a degasification monitoring point (metric tons CH4).
* * * * *
(c) If gas from a degasification system or ventilation system is
sold, used onsite, or otherwise destroyed (including by flaring or VAM
oxidation), you must calculate the quarterly CH4 destroyed
for each destruction device and each point of offsite transport to a
destruction device, using Equation FF-5 of this section. You must
measure CH4 content and flow rate according to the
provisions in Sec. 98.324, and calculate the methane routed to the
destruction device (CH4) using either Equation FF-
[[Page 19864]]
1 or Equation FF-4 of this section, as applicable.
* * * * *
(1) * * *
[GRAPHIC] [TIFF OMITTED] TP02AP13.004
* * * * *
0
68. Section 98.324 is amended by revising paragraphs (b) introductory
text, (c)(2), and parameter ``CCH4'' of Equation FF-9 to
read as follows:
Sec. 98.324 Monitoring and QA/QC requirements.
* * * * *
(b) For CH4 liberated from ventilation systems,
determine whether CH4 will be monitored from each
ventilation shaft and vent hole, from a centralized monitoring point,
or from a combination of the two options. Operators are allowed
flexibility for aggregating emissions from more than one ventilation
point, as long as emissions from all are addressed, and the methodology
for calculating total emissions documented. Monitor by one of the
following options:
* * * * *
(c) * * *
(2) Collect weekly (once each calendar week, with at least three
days between measurements) or more frequent samples, for all
degasification wells and gob gas vent holes. Determine weekly or more
frequent flow rates, methane concentration, temperature, and pressure
from these degasification wells and gob gas vent holes. Methane
composition should be determined either by submitting samples to a lab
for analysis, or from the use of methanometers at the degasification
monitoring site. Follow the sampling protocols for sampling of methane
emissions from ventilation shafts, as described in Sec. 98.324(b)(1).
You must record the date of sampling, flow, temperature, pressure, and
moisture measurements, the methane concentration (percent), the bottle
number of samples collected, and the location of the measurement or
collection.
* * * * *
(d) * * *
(2) * * *
(iii) * * *
* * * * *
CCH4 = Methane (CH4) concentration in the gas
(volume %) for use in Equations FF-1 and FF-3 of this subpart.
* * * * *
0
69. Section 98.326 is amended by revising paragraphs (a), (f), (h),
(i), (j), (o), and (r), and adding paragraphs (r)(1), (r)(2), (r)(3),
(t), and (u) to read as follows:
Sec. 98.326 Data reporting requirements.
* * * * *
(a) Quarterly CH4 liberated from each ventilation
monitoring point, (metric tons CH4).
* * * * *
(f) Quarterly volumetric flow rate for each ventilation monitoring
point and units of measure (scfm or acfm), date and location of each
measurement, and method of measurement (quarterly sampling or
continuous monitoring), used in Equation FF-1 of this subpart.
* * * * *
(h) Weekly volumetric flow rate used to calculate CH4
liberated from degasification systems and units of measure (acfm or
scfm), and method of measurement (sampling or continuous monitoring),
used in Equation FF-3 of this subpart.
(i) Quarterly CH4 concentration (%) used to calculate
CH4 liberated from degasification systems and if the data is
based on CEMS or weekly sampling.
(j) Weekly volumetric flow rate used to calculate CH4
destruction for each destruction device and each point of offsite
transport, and units of measure (acfm or scfm).
* * * * *
(o) Temperatures ([deg]R), pressure (atm), moisture content, and
the moisture correction factor (if applicable) used in Equation FF-1
and FF-3 of this subpart; and the gaseous organic concentration
correction factor, if Equation FF-9 was required.
* * * * *
(r) Identification information and description for each well and
shaft, including paragraphs (r)(1) through (r)(3) of this section:
(1) Indication of whether the well or shaft is monitored
individually, or as part of a centralized monitoring point. Note which
method (sampling or continuous monitoring) was used.
(2) Start date and close date of each well or shaft.
(3) Number of days the well or shaft was in operation during the
reporting year.
* * * * *
(t) Quarterly CH4 routed to each destruction device or
offsite transfer point used in Equation FF-5 of this subpart (metric
tons).
(u) Mine Safety and Health Administration (MSHA) identification for
this coal mine.
Subpart HH--[AMENDED]
0
70. Section 98.343 is amended by:
0
a. Revising the parameters ``DOC'' and ``F'' of Equation HH-1.
0
b. Revising Equation HH-4 and the parameters ``N'' and ``0.0423'' of
Equation HH-4.
0
c. Revising paragraphs (b)(2)(i), (b)(2)(ii), (b)(2)(iii)(A), and
(b)(2)(iii)(B).
0
d. Revising parameter ``OX'' of Equation HH-5 at paragraph (c)(1).
0
e. Revising paragraphs (c)(3)(i) and (c)(3)(ii).
Sec. 98.343 Calculating GHG emissions.
(a) * * *
(1) * * *
* * * * *
DOC = Degradable organic carbon from Table HH-1 of this subpart
[fraction (metric tons C/metric ton waste)].
* * * * *
F = Fraction by volume of CH4 in landfill gas from
measurement data for the current reporting year, if available
(fraction, dry basis, corrected to 0 percent oxygen); otherwise, use
the default of 0.5.
* * * * *
(b) * * *
(1) * * *
[GRAPHIC] [TIFF OMITTED] TP02AP13.005
[[Page 19865]]
* * * * *
N = Total number of measurement periods in a year. Use daily
averaging periods for a continuous monitoring system and N = 365 (or
N = 366 for leap years). For monthly sampling, as provided in
paragraph (b)(2) of this section, use N=12.
* * * * *
0.0423 = Density of CH4 lb/cf at 520[deg]R or 60 degrees
Fahrenheit and 1 atm.
* * * * *
(2) * * *
(i) Continuously monitor gas flow rate and determine the cumulative
volume of landfill gas each month and the cumulative volume of landfill
gas each year that is collected and routed to a destruction device
(before any treatment equipment). Under this option, the gas flow meter
is not required to automatically correct for temperature, pressure, or,
if necessary, moisture content. If the gas flow meter is not equipped
with automatic correction for temperature, pressure, or, if necessary,
moisture content, you must determine these parameters as specified in
paragraph (b)(2)(iii) of this section.
(ii) Determine the CH4 concentration in the landfill gas
that is collected and routed to a destruction device (before any
treatment equipment) in a location near or representative of the
location of the gas flow meter at least once each calendar month; if
only one measurement is made each calendar month, there must be at
least fourteen days between measurements.
(iii) * * *
(A) Determine the temperature and pressure in the landfill gas that
is collected and routed to a destruction device (before any treatment
equipment) in a location near or representative of the location of the
gas flow meter at least once each calendar month; if only one
measurement is made each calendar month, there must be at least
fourteen days between measurements.
(B) If the CH4 concentration is determined on a dry
basis and flow is determined on a wet basis or CH4
concentration is determined on a wet basis and flow is determined on a
dry basis, and the flow meter does not automatically correct for
moisture content, determine the moisture content in the landfill gas
that is collected and routed to a destruction device (before any
treatment equipment) in a location near or representative of the
location of the gas flow meter at least once each calendar month; if
only one measurement is made each calendar month, there must be at
least fourteen days between measurements.
(c) * * *
(1) * * *
* * * * *
OX = Oxidation fraction. Use the appropriate oxidation fraction
default value from Table HH-4 of this subpart.
* * * * *
(3) * * *
(i) Calculate CH4 emissions from the modeled
CH4 generation and measured CH4 recovery using
Equation HH-6 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.006
Where:
Emissions = Methane emissions from the landfill in the reporting
year (metric tons CH4).
GCH4 = Modeled methane generation rate in reporting year
from Equation HH-1 of this section or the quantity of recovered
CH4 from Equation HH-4 of this section, whichever is
greater (metric tons CH4).
N = Number of landfill gas measurement locations (associated with a
destruction device or gas sent off-site). If a single monitoring
location is used to monitor volumetric flow and CH4
concentration of the recovered gas sent to one or multiple
destruction devices, then N=1.
Rn = Quantity of recovered CH4 from Equation
HH-4 of this section for the nth measurement location
(metric tons).
OX = Oxidation fraction. Use the appropriate oxidation fraction
default value from Table HH-4 of this subpart.
DEn = Destruction efficiency (lesser of manufacturer's
specified destruction efficiency and 0.99) for the nth
measurement location. If the gas is transported off-site for
destruction, use DE = 1. If the volumetric flow and CH4
concentration of the recovered gas is measured at a single location
providing landfill gas to multiple destruction devices (including
some gas destroyed on-site and some gas sent off-site for
destruction), calculate DEn as the arithmetic average of
the DE values determined for each destruction device associated with
that measurement location.
fDest, n = Fraction of hours the destruction device
associated with the nth measurement location was operating during
active gas flow calculated as the annual operating hours for the
destruction device divided by the annual hours flow was sent to the
destruction device as measured at the nth measurement
location. If the gas is destroyed in a back-up flare (or similar
device) or if the gas is transported off-site for destruction, use
fDest= 1. If the volumetric flow and CH4
concentration of the recovered gas is measured at a single location
providing landfill gas to multiple destruction devices (including
some gas destroyed on-site and some gas sent off-site for
destruction), calculate fDest, n as the arithmetic
average of the fDest values determined for each
destruction device associated with that measurement location.
(ii) Calculate CH4 generation and CH4
emissions using measured CH4 recovery and estimated gas
collection efficiency and Equations HH-7 and HH-8 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.007
[[Page 19866]]
Where:
MG = Methane generation, adjusted for oxidation, from the landfill
in the reporting year (metric tons CH4).
Emissions = Methane emissions from the landfill in the reporting
year (metric tons CH4).
N = Number of landfill gas measurement locations (associated with a
destruction device or gas sent off-site). If a single monitoring
location is used to monitor volumetric flow and CH4
concentration of the recovered gas sent to one or multiple
destruction devices, then N=1.
Rn = Quantity of recovered CH4 from Equation
HH-4 of this section for the nth measurement location
(metric tons CH4).
CE = Collection efficiency estimated at landfill, taking into
account system coverage, operation, and cover system materials from
Table HH-3 of this subpart. If area by soil cover type information
is not available, use default value of 0.75 (CE4 in table HH-3 of
this subpart) for all areas under active influence of the collection
system.
fRec, n = Fraction of hours the recovery system
associated with the nth measurement location was operating (annual
operating hours/8760 hours per year or annual operating hours/8784
per year for a leap year).
OX = Oxidation fraction. Use appropriate oxidation fraction default
value from Table HH-4 of this subpart.
DEn = Destruction efficiency, (lesser of
manufacturer's specified destruction efficiency and 0.99) for the
nth measurement location. If the gas is transported off-
site for destruction, use DE = 1. If the volumetric flow and
CH4 concentration of the recovered gas is measured at a
single location providing landfill gas to multiple destruction
devices (including some gas destroyed on-site and some gas sent off-
site for destruction), calculate DEn as the arithmetic
average of the DE values determined for each destruction device
associated with that measurement location.
fDest,n = Fraction of hours the destruction device
associated with the nth measurement location was
operating during active gas flow calculated as the annual operating
hours for the destruction device divided by the annual hours flow
was sent to the destruction device as measured at the nth
measurement location. If the gas is destroyed in a back-up flare (or
similar device) or if the gas is transported off-site for
destruction, use fDest = 1. If the volumetric flow and
CH4 concentration of the recovered gas is measured at a
single location providing landfill gas to multiple destruction
devices (including some gas destroyed on-site and some gas sent off-
site for destruction), calculate fDest,n as the
arithmetic average of the fDest values determined for
each destruction device associated with that measurement location.
0
71. Section 98.344 is amended by revising paragraph (e) and adding
paragraph (f) to read as follows:
Sec. 98.344 Monitoring and QA/QC requirements.
* * * * *
(e) For landfills electing to measure the fraction by volume of
CH4 in landfill gas (F), follow the requirements in
paragraphs (e)(1) and (e)(2) of this section.
(1) Use a gas composition monitor capable of measuring the
concentration of CH4 on a dry basis that is properly
operated, calibrated, and maintained according to the requirements
specified in paragraph (b) of this section. You must either use a gas
composition monitor that is also capable of measuring the O2
concentration correcting for excess (infiltration) air or you must
operate, maintain, and calibrate a second monitor capable of measuring
the O2 concentration on a dry basis according to the
manufacturer's specifications.
(2) Use Equation HH-10 of this section to correct the measured
CH4 concentration to 0% oxygen. If multiple CH4
concentration measurements are made during the reporting year,
determine F separately for each measurement made during the reporting
year, and use the results to determine the arithmetic average value of
F for use in Equation HH-1 of this part.
[GRAPHIC] [TIFF OMITTED] TP02AP13.008
Where:
F = Fraction by volume of CH4 in landfill gas (fraction,
dry basis, corrected to 0% oxygen).
CCH4 = Measured CH4 concentration in landfill
gas (volume %, dry basis).
20.9c = Defined O2 correction basis, (volume
%, dry basis).
20.9 = O2 concentration in air (volume %, dry basis).
%O2 = Measured O2 concentration in landfill
gas (volume %, dry basis).
(f) The owner or operator shall document the procedures used to
ensure the accuracy of the estimates of disposal quantities and, if
applicable, gas flow rate, gas composition, temperature, pressure, and
moisture content measurements. These procedures include, but are not
limited to, calibration of weighing equipment, fuel flow meters, and
other measurement devices. The estimated accuracy of measurements made
with these devices shall also be recorded, and the technical basis for
these estimates shall be provided.
0
72. Section 98.345 is amended by revising paragraph (c) to read as
follows:
Sec. 98.345 Procedures for estimating missing data.
* * * * *
(c) For missing daily waste disposal quantity data for disposal in
the reporting year, the substitute value shall be the average daily
waste disposal quantity for that day of the week as measured on the
week before and week after the missing daily data.
0
73. Section 98.346 is amended by revising paragraphs (d)(1), (e), (h),
(i)(5), (i)(8), (i)(10), (i)(11), and (i)(12) to read as follows:
Sec. 98.346 Data reporting requirements.
* * * * *
(d) * * *
(1) Degradable organic carbon (DOC) and fraction of DOC
dissimilated (DOCF) values used in the calculations.
* * * * *
(e) Fraction of CH4 in landfill gas (F), an indication
of whether the fraction of CH4 was determined based on
measured values or the default value, and the methane correction factor
used in the calculations. If an MCF other than the default of 1 is
used, provide an indication of whether active aeration of the waste in
the landfill was conducted during the reporting year, a description of
the aeration system, including aeration blower capacity, the fraction
of the landfill containing waste affected by aeration, the total number
of hours during the year the aeration blower was operated, and other
factors used as a basis for the selected MCF value.
* * * * *
(h) For landfills without gas collection systems, the annual
methane emissions (i.e., the methane generation, adjusted for
oxidation, calculated using Equation HH-5 of this subpart), reported in
metric tons CH4, the oxidation fraction used in the
calculation, and an indication of whether passive vents and/or passive
flares (vents or flares that are not considered part of the gas
collection system as defined in Sec. 98.6) are present at this
landfill.
[[Page 19867]]
(i) * * *
(5) An indication of whether destruction occurs at the landfill
facility, off-site, or both. If destruction occurs at the landfill
facility, also report for each measurement location an indication of
whether a back-up destruction device is present at the landfill, the
annual operating hours for the primary destruction device, the annual
operating hours for the back-up destruction device (if present), and
the destruction efficiency used (percent).
* * * * *
(8) Methane generation corrected for oxidation calculated using
Equation HH-5 of this subpart, reported in metric tons CH4,
and the oxidation fraction used in the calculation.
* * * * *
(10) Methane generation corrected for oxidation calculated using
Equation HH-7 of this subpart, reported in metric tons CH4,
and the oxidation fraction used in the calculation.
(11) Methane emissions calculated using Equation HH-6 of this
subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation.
(12) Methane emissions calculated using Equation HH-8 of this
subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation.
0
74. Section 98.348 is amended by adding definitions for ``Landfill
capacity'' and ``Leachate recirculation'' in alphabetical order to read
as follows:
Sec. 98.348 Definitions.
* * * * *
Landfill capacity means the maximum amount of solid waste a
landfill can accept. For the purposes of this subpart, for landfills
that have a permit, the landfill capacity can be determined in terms of
volume or mass in the most recent permit issued by the state, local, or
Tribal agency responsible for regulating the landfill, plus any in-
place waste not accounted for in the most recent permit. If the owner
or operator chooses to convert from volume to mass to determine its
capacity, the calculation must include a site-specific density.
Leachate recirculation means the practice of taking the leachate
collected from the landfill and reapplying it to the landfill by any of
one of a variety of methods, including pre-wetting of the waste, direct
discharge into the working face, spraying, infiltration ponds, vertical
injection wells, horizontal gravity distribution systems, and pressure
distribution systems.
* * * * *
0
75. Table HH-1 to Subpart HH is amended by revising the entry for
``OX'' as follows:
Table HH-1 to Subpart HH of Part 98--Emissions Factors, Oxidation
Factors and Methods
------------------------------------------------------------------------
Factor Default value Units
------------------------------------------------------------------------
* * * * *
Other parameters--All MSW landfills
------------------------------------------------------------------------
* * * * *
OX.................................. See Table HH-4 of this .........
subpart.
* * * * *
------------------------------------------------------------------------
0
76. Table HH-2 to Subpart HH is revised to read as follows:
Table HH-2 to Subpart HH of Part 98--U.S. Per Capita Waste Disposal
Rates
------------------------------------------------------------------------
Waste per
Year capita ton/cap/
yr
------------------------------------------------------------------------
1950.................................................... 0.63
1951.................................................... 0.63
1952.................................................... 0.63
1953.................................................... 0.63
1954.................................................... 0.63
1955.................................................... 0.63
1956.................................................... 0.63
1957.................................................... 0.63
1958.................................................... 0.63
1959.................................................... 0.63
1960.................................................... 0.63
1961.................................................... 0.64
1962.................................................... 0.64
1963.................................................... 0.65
1964.................................................... 0.65
1965.................................................... 0.66
1966.................................................... 0.66
1967.................................................... 0.67
1968.................................................... 0.68
1969.................................................... 0.68
1970.................................................... 0.69
1971.................................................... 0.69
1972.................................................... 0.70
1973.................................................... 0.71
1974.................................................... 0.71
1975.................................................... 0.72
1976.................................................... 0.73
1977.................................................... 0.73
1978.................................................... 0.74
1979.................................................... 0.75
1980.................................................... 0.75
1981.................................................... 0.76
1982.................................................... 0.77
1983.................................................... 0.77
1984.................................................... 0.78
1985.................................................... 0.79
1986.................................................... 0.79
1987.................................................... 0.80
1988.................................................... 0.80
1989.................................................... 0.83
1990.................................................... 0.82
1991.................................................... 0.76
1992.................................................... 0.74
1993.................................................... 0.76
1994.................................................... 0.75
1995.................................................... 0.70
1996.................................................... 0.68
1997.................................................... 0.69
1998.................................................... 0.75
1999.................................................... 0.75
2000.................................................... 0.80
2001.................................................... 0.91
2002.................................................... 1.02
2003.................................................... 1.02
2004.................................................... 1.01
2005.................................................... 0.98
2006.................................................... 0.95
2007.................................................... 0.95
2008.................................................... 0.95
2009 and all later years................................ 0.95
------------------------------------------------------------------------
0
77. Table HH-4 to Subpart HH is added to read as follows:
Table HH-4 to Subpart HH of Part 98--Landfill Methane Oxidation
Fractions
------------------------------------------------------------------------
Use this
landfill
If your methane flux rate\a\ for the reporting year is: methane
oxidation
fraction:
------------------------------------------------------------------------
Less than 10 grams per square meter per day (g/m\2\/d).. 0.35
10 to 70 g/m\2\/d....................................... 0.25
Greater than 70 g/m\2\/d................................ 0.10
------------------------------------------------------------------------
\a\Methane flux rate (in grams per square meter per day; g/m\2\/d) is
the mass flow rate of methane per unit area at the bottom of the
surface soil prior to any oxidation and is calculated as follows.
[[Page 19868]]
[GRAPHIC] [TIFF OMITTED] TP02AP13.009
Where:
MF = Methane flux rate from the landfill in the reporting year
(grams per square meter per day, g/m\2\/d).
K = unit conversion factor = 10\6\/365 (g/metric ton per days/year)
or 10\6\/366 for a leap year.
SArea = The surface area of the landfill containing waste at the
beginning of the reporting year (square meters, m\2\).
GCH4 = Modeled methane generation rate in reporting year
from Equation HH-1 of this subpart, or, for application with
Equation HH-6 only, the greater of the modeled methane generation
rate in reporting year from Equation HH-1 of this subpart and the
quantity of recovered CH4 from Equation HH-4 of this
subpart (metric tons CH4).
CE = Collection efficiency estimated at landfill, taking into
account system coverage, operation, and cover system materials from
Table HH-3 of this subpart. If area by soil cover type information
is not available, use default value of 0.75 (CE4 in table HH-3 of
this subpart) for all areas under active influence of the collection
system.
N = Number of landfill gas measurement locations (associated with a
destruction device or gas sent off-site). If a single monitoring
location is used to monitor volumetric flow and CH4
concentration of the recovered gas sent to one or multiple
destruction devices, then N=1.
Rn = Quantity of recovered CH4 from Equation
HH-4 of this subpart for the nth measurement location (metric tons).
fRec,n = Fraction of hours the recovery system associated
with the nth measurement location was operating (annual operating
hours/8760 hours per year or annual operating hours/8784 hours per
year for a leap year).
Subpart II--[AMENDED]
0
78. Section 98.353 is amended by revising the parameters
``fDest--1'' and ``fDest--2'' of Equation II-6 to
read as follows:
Sec. 98.353 Calculating GHG emissions.
* * * * *
(d) * * *
(2) * * *
* * * * *
fDest1 = Fraction of hours the primary destruction device
was operating calculated as the annual hours when the destruction
device was operating divided by the annual operating hours of the
biogas recovery system. If the biogas is transported off-site for
destruction, use fDest = 1.
* * * * *
fDest2 = Fraction of hours the back-up destruction device
was operating calculated as the annual hours when the destruction
device was operating divided by the annual operating hours of the
biogas recovery system.
* * * * *
Subpart LL--[AMENDED]
0
79. Section 98.386 is amended by:
0
a. Removing and reserving paragraphs (a)(1) and (a)(5).
0
b. Revising paragraph (a)(4), (a)(8), (a)(9)(v), and (a)(11)(v).
0
c. Removing and reserving paragraph (a)(13).
0
d. Revising paragraphs (a)(14), (a)(15) and (a)(18).
0
e. Removing and reserving paragraph (b)(1).
0
f. Revising paragraphs (b)(4), (b)(5)(v), and (b)(6)(i).
0
g. Removing and reserving paragraph (c)(1).
0
h. Revising paragraphs (c)(4), (c)(5)(v), (d)(2), and (d)(3) to read as
follows:
Sec. 98.386 Data reporting requirements.
* * * * *
(a) * * *
(4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(2) of this section.
* * * * *
(8) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(6) of this section.
(9) * * *
(v) The calculated CO2 emissions factor in metric tons
CO2 per barrel or per metric ton of product.
* * * * *
(11) * * *
(v) The calculated CO2 emissions factor in metric tons
CO2 per barrel or metric ton of product.
* * * * *
(14) For each specific type of biomass that enters the coal-to-
liquid facility to be co-processed with fossil fuel-based feedstock to
produce a product reported in paragraph (a)(6) of this section, report
the annual quantity in metric tons or barrels.
(15) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(14) of this section.
* * * * *
(18) Annual CO2 emissions in metric tons that would
result from the complete combustion or oxidation of
[[Page 19869]]
each type of biomass feedstock co-processed with fossil fuel-based
feedstocks reported in paragraph (a)(14) of this section, calculated
according to Sec. 98.393(c).
* * * * *
(b) * * *
(4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (b)(2) of this section.
(5) * * *
(v) The calculated CO2 emissions factor in metric tons
per barrel or per metric ton of product.
(6) * * *
(i) The density test results in metric tons per barrel.
* * * * *
(c) * * *
(4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (c)(2) of this section.
(5) * * *
(v) The calculated CO2 emissions factor in metric tons
per barrel or per metric ton of product.
* * * * *
(d) * * *
(2) For a product that enters the facility to be further refined or
otherwise used on site that is a blended feedstock, producers must meet
the reporting requirements of paragraph (a)(2) of this section by
reflecting the individual components of the blended feedstock.
(3) For a product that is produced, imported, or exported that is a
blended product, producers, importers, and exporters must meet the
reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this
section, as applicable, by reflecting the individual components of the
blended product.
Subpart MM--[AMENDED]
0
80. Section 98.393 is amended by:
0
a. Revising the parameter ``Producti'' to Equation MM-1 in
paragraph (a)(1).
0
b. Revising the parameter ``Producti'' to Equation MM-1 in
paragraph (a)(2).
0
c. Revising paragraphs (h)(1) introductory text and (h)(2) introductory
text.
Sec. 98.393 Calculating GHG emissions.
(a) * * *
(1) * * *
* * * * *
Producti = Annual volume of product ``i'' produced,
imported, or exported by the reporting party (barrels). For
refiners, this volume only includes products ex refinery gate, and
excludes products that entered the refinery but are not reported
under Sec. 98.396(a)(2). For natural gas liquids, volumes shall
reflect the individual components of the product as listed in Table
MM-1 to subpart MM.
* * * * *
(2) * * *
* * * * *
Producti = Annual mass of product ``i'' produced,
imported, or exported by the reporting party (metric tons). For
refiners, this mass only includes products ex refinery gate, and
excludes products that entered the refinery but are not reported
under Sec. 98.396(a)(2).
* * * * *
(h) * * *
(1) A reporter using Calculation Method 1 to determine the emission
factor of a petroleum product shall calculate the CO2
emissions associated with that product using Equation MM-8 of this
section in place of Equation MM-1 of this section.
* * * * *
(2) A refinery using Calculation Method 1 of this subpart to
determine the emission factor of a non-crude petroleum feedstock shall
calculate the CO2 emissions associated with that feedstock
using Equation MM-9 of this section in place of Equation MM-2 of this
section.
* * * * *
0
81. Section 98.394 is amended by:
0
a. Revising paragraphs (a)(1) introductory text and (a)(3).
0
b. Adding paragraph (b)(3).
0
c. Revising paragraph (c) introductory text.
0
d. Removing and reserving paragraph (d).
Sec. 98.394 Monitoring and QA/QC requirements.
(a) * * *
(1) The quantity of petroleum products, natural gas liquids, and
biomass, shall be determined as follows:
* * * * *
(3) The annual quantity of crude oil received shall be determined
according to one of the following methods. You may use an appropriate
standard method published by a consensus-based standards organization
or you may use an industry standard practice.
(b) * * *
(3) For units and processes that operate continuously with
infrequent outages, it may not be possible to complete the calibration
of a flow meter or other measurement device without disrupting normal
process operation. In such cases, the owner or operator may postpone
the calibration until the next scheduled maintenance outage. The best
available information from company records may be used in the interim.
Such postponements shall be documented in the monitoring plan that is
required under Sec. 98.3(g)(5).
(c) Procedures for Calculation Method 2 of this subpart.
* * * * *
0
82. Section 98.395 is amended by:
0
a. Revising paragraph (a) introductory text.
0
b. Revising paragraph (b).
0
c. Removing paragraph (c).
Sec. 98.395 Procedures for estimating missing data.
(a) Determination of quantity. Whenever the quality assurance
procedures in Sec. 98.394(a) cannot be followed to measure the
quantity of one or more petroleum products, natural gas liquids, types
of biomass, feedstocks, or crude oil during any period (e.g., if a
meter malfunctions), the following missing data procedures shall be
used:
* * * * *
(b) Determination of emission factor. Whenever any of the
procedures in Sec. 98.394(c) cannot be followed to develop an emission
factor for any reason, Calculation Method 1 of this subpart must be
used in place of Calculation Method 2 of this subpart for the entire
reporting year.
0
83. Section 98.396 is amended by:
0
a. Removing and reserving paragraph (a)(1).
0
b. Revising paragraph (a)(4).
0
c. Removing and reserving paragraph (a)(5).
0
d. Revising paragraphs (a)(8), (a)(9) introductory text, (a)(9)(iii),
(a)(9)(v), (a)(10) introductory text, (a)(11) introductory text, and
(a)(11)(iii).
0
e. Removing and reserving paragraph (a)(13).
0
f. Revising paragraphs (a)(15) and (a)(18).
0
g. Revising paragraphs (a)(20), (a)(21) and (a)(22).
0
h. Removing paragraph (a)(23).
0
i. Removing and reserving paragraph (b)(1).
0
j. Revising paragraphs (b)(2), (b)(4), (b)(5) introductory text, and
(b)(6) introductory text.
0
k. Removing and reserving paragraph (c)(1).
0
l. Revising paragraph (c)(4), (c)(5) introductory text, (c)(6)
introductory text, (d)(2), and (d)(3).
Sec. 98.396 Data reporting requirements.
* * * * *
(a) * * *
(1) [Reserved]
* * * * *
(4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(2) of this section.
(5) [Reserved]
* * * * *
[[Page 19870]]
(8) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(6) of this section.
(9) For every feedstock reported in paragraph (a)(2) of this
section for which Calculation Method 2 of this subpart was used to
determine an emissions factor, report:
* * * * *
(iii) The carbon share test results in percent mass.
* * * * *
(v) The calculated CO2 emissions factor in metric tons
CO2 per barrel or per metric ton of product.
(10) For every non-solid feedstock reported in paragraph (a)(2) of
this section for which Calculation Method 2 of this subpart was used to
determine an emissions factor, report:
* * * * *
(11) For every petroleum product and natural gas liquid reported in
paragraph (a)(6) of this section for which Calculation Method 2 of this
subpart was used to determine an emissions factor, report:
* * * * *
(iii) The carbon share test results in percent mass.
* * * * *
(13) [Reserved]
* * * * *
(15) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(14) of this section.
* * * * *
(18) The CO2 emissions in metric tons that would result
from the complete combustion or oxidation of each type of biomass
feedstock co-processed with petroleum feedstocks reported in paragraph
(a)(14) of this section, calculated according to Sec. 98.393(c).
* * * * *
(20) For all crude oil that enters the refinery, report the annual
quantity in barrels.
(21) The quantity of bulk NGLs in metric tons or barrels received
for processing during the reporting year. Report only quantities of
bulk NGLs not reported in (a)(2) of this section.
(22) Volume of crude oil in barrels that you injected into a crude
oil supply or reservoir.
(b) In addition to the information required by Sec. 98.3(c), each
importer shall report all of the following information at the corporate
level:
(1) [Reserved]
(2) For each petroleum product and natural gas liquid listed in
Table MM-1 of this subpart, report the annual quantity in metric tons
or barrels. For natural gas liquids, quantity shall reflect the
individual components of the product.
* * * * *
(4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (b)(2) of this section.
(5) For each product reported in paragraph (b)(2) of this section
for which Calculation Method 2 of this subpart used was used to
determine an emissions factor, report:
* * * * *
(6) For each non-solid product reported in paragraph (b)(2) of this
section for which Calculation Method 2 of this subpart was used to
determine an emissions factor, report:
* * * * *
(c) * * *
(1) [Reserved]
* * * * *
(4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (c)(2) of this section.
(5) For each product reported in paragraph (c)(2) of this section
for which Calculation Method 2 of this subpart was used to determine an
emissions factor, report:
* * * * *
(6) For each non-solid product reported in paragraph (c)(2) of this
section for which Calculation Method 2 of this subpart used was used to
determine an emissions factor, report:
* * * * *
(d) * * *
(2) For a product that enters the refinery to be further refined or
otherwise used on site that is a blended non-crude feedstock, refiners
must meet the reporting requirements of paragraphs (a)(2) of this
section by reflecting the individual components of the blended non-
crude feedstock.
(3) For a product that is produced, imported, or exported that is a
blended product, refiners, importers, and exporters must meet the
reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this
section, as applicable, by reflecting the individual components of the
blended product.
0
84. Section 98.397 is amended by revising paragraphs (b) and (d) to
read as follows:
Sec. 98.397 Records that must be retained.
* * * * *
(b) Reporters shall maintain records to support quantities that are
reported under this subpart, including records documenting any
estimations of missing data and the number of calendar days in the
reporting year for which substitute data procedures were followed. For
all reported quantities of petroleum products, natural gas liquids, and
biomass, reporters shall maintain metering, gauging, and other records
normally maintained in the course of business to document product and
feedstock flows including the date of initial calibration and the
frequency of recalibration for the measurement equipment used.
* * * * *
(d) Reporters shall maintain laboratory reports, calculations and
worksheets used in the measurement of density and carbon share for any
petroleum product or natural gas liquid for which CO2
emissions were calculated using Calculation Method 2.
* * * * *
0
85. Section 98.398 is amended by:
0
a. Adding the definitions for ``Bulk NGLs'' and ``Natural Gas Liquids
(NGLs)'' in alphabetical order.
0
b. Removing the definition of ``Batch''.
Sec. 98.398 Definitions.
* * * * *
Bulk NGLs for purposes of reporting under this subpart means
mixtures of NGLs that are sold or delivered as undifferentiated
product.
Natural Gas Liquids (NGLs) for the purposes of reporting under this
subpart means hydrocarbons that are separated from natural gas as
liquids through the process of absorption, condensation, adsorption, or
other methods, and are sold or delivered as differentiated product.
Generally, such liquids consist of ethane, propane, butanes, or
pentanes plus.
0
86. Table MM-1 to Subpart MM is amended by:
0
a. Revising the entries for Ethane, Ethylene, Propane, Propylene,
Butane, Butylene, Isobutane, and Isobutylene.
0
b. Adding footnotes 3 and 4.
[[Page 19871]]
Table MM-1 to Subpart MM of Part 98--Default Factors for Petroleum
Products and Natural Gas Liquids\1 2\
------------------------------------------------------------------------
Column C:
Column A: Column B: emission
density carbon factor
Products (metric share (% (metric
tons/bbl) of mass) tons CO2/
bbl)
------------------------------------------------------------------------
* * * * * * *
Other Petroleum Products and Natural Gas Liquids
* * * * * * *
Ethane\3\........................ 0.0579 79.89 0.170
Ethylene\4\...................... 0.0492 85.63 0.154
Propane\3\....................... 0.0806 81.71 0.241
Propylene\3\..................... 0.0827 85.63 0.260
Butane\3\........................ 0.0928 82.66 0.281
Butylene\3\...................... 0.0972 85.63 0.305
Isobutane\3\..................... 0.0892 82.66 0.270
Isobutylene\3\................... 0.0949 85.63 0.298
* * * * * * *
------------------------------------------------------------------------
\1\ In the case of products blended with some portion of biomass-based
fuel, the carbon share in Table MM-1 of this subpart represents only
the petroleum-based components.
\2\ Products that are derived entirely from biomass should not be
reported, but products that were derived from both biomass and a
petroleum product (i.e., co-processed) should be reported as the
petroleum product that it most closely represents.
\3\ The density and emission factors for components of LPG determined at
60 degrees Fahrenheit and saturation pressure (LPGs other than
ethylene)
\4\ The density and emission factor for ethylene determined at 41
degrees Fahrenheit and saturation pressure.
Subpart NN--[AMENDED]
0
87. Section 98.400 is amended by revising paragraphs (a) and (b) to
read as follows:
Sec. 98.400 Definition of the source category.
* * * * *
(a) Natural gas liquids fractionators are installations that
fractionate natural gas liquids (NGLs) into their constituent liquid
products or mixtures of products (ethane, propane, normal butane,
isobutane or pentanes plus) for supply to downstream facilities.
(b) Local Distribution Companies (LDCs) are companies that own or
operate distribution pipelines, not interstate pipelines or intrastate
pipelines, that physically deliver natural gas to end users and that
are within a single state that are regulated as separate operating
companies by State public utility commissions or that operate as
independent municipally-owned distribution systems. LDCs do not include
pipelines (both interstate and intrastate) delivering natural gas
directly to major industrial users and farm taps upstream of the local
distribution company inlet.
* * * * *
0
88. Section 98.403 is amended by:
0
a. Revising the parameter ``Fuelh'' to Equation NN-2.
0
b. Revising paragraphs (b)(1) introductory text and (b)(2)(i).
0
c. Revising parameters ``CO2k'' and ``Fuel'' to Equation NN-
4.
0
d. Revising paragraph (b)(3).
0
e. Revising paragraph (b)(4).
0
f. Revising paragraph (c)(2) introductory text.
0
g. Revising parameter ``CO2'' to Equation NN-8.
Sec. 98.403 Calculating GHG emissions.
(a) * * *
(2) * * *
* * * * *
Fuelh = Total annual volume of product ``h'' supplied
(volume per year, in Mscf for natural gas and bbl for NGLs).
* * * * *
(b) * * *
(1) For natural gas that is received for redelivery to downstream
gas transmission pipelines and other local distribution companies, use
Equation NN-3 of this section and the default values for the
CO2 emission factors found in Table NN-2 of this subpart.
Alternatively, reporter-specific CO2 emission factors may be
used, provided they are developed using methods outlined in Sec.
98.404.
* * * * *
(2)(i) For natural gas delivered to end-users registering a supply
equal to or greater than 460,000 Mscf per year, use Equation NN-4 of
this section and the default values for the CO2 emission
factors found in Table NN-2 of this subpart.
(ii) * * *
* * * * *
CO2 k = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to
each end-user that receives a supply equal to or greater than
460,000 Mscf per year (metric tons).
Fuel = Total annual volume of natural gas supplied to this end-user,
if known, otherwise, the annual volume supplied to this meter (Mscf
per year).
* * * * *
(3) For the net change in natural gas stored on system by the LDC
during the reporting year, use Equation NN-5a of this section. For
natural gas that is received by means other than through the city gate,
and is not otherwise accounted for by Equation NN-1 or NN-2 of this
section, use Equation NN-5b of this section.
(i) For natural gas received by the LDC that is injected into on-
system storage, and/or liquefied and stored, and for gas removed from
storage and used for deliveries, use Equation NN-5a of this section and
the default value for the CO2 emission factors found in
Table NN-2 of this subpart. Alternatively, a reporter-specific
CO2 emission factor may be used, provided it is developed
using methods outlined in Sec. 98.404.
[[Page 19872]]
[GRAPHIC] [TIFF OMITTED] TP02AP13.031
Where:
CO2l = Annual CO2 mass emissions that would
result from the combustion or oxidation of the net change in natural
gas stored on system by the LDC within the reporting year (metric
tons).
Fuel1 = Total annual volume of natural gas added to
storage on-system or liquefied and stored in the reporting year
(Mscf per year).
Fuel2 = Total annual volume of natural gas that is
removed from storage or vaporized and removed from storage and used
for deliveries to customers or other LDCs by the LDC within the
reporting year (Mscf per year).
EF = Annual average CO2 emission factor for natural gas
placed into/removed from storage (MT CO2/Mscf).
(ii) For natural gas received by the LDC that bypassed the city
gate, use Equation NN-5b of this section. This includes natural gas
received directly by LDC systems from producers or natural gas
processing plants from local production, received as a liquid and
vaporized for delivery, or received from any other source that bypassed
the city gate. Use the default value for the CO2 emission
factors found in Table NN-2 of this subpart. Alternatively, a reporter-
specific CO2 emission factor may be used, provided it is
developed using methods outlined in Sec. 98.404.
[GRAPHIC] [TIFF OMITTED] TP02AP13.032
Where:
CO2n = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas received that
bypassed the city gate and is not otherwise accounted for by
Equation NN-1 or NN-2 of this section (metric tons).
Fuelz = Total annual volume of natural gas received that
was not otherwise accounted for by Equation NN-1 or NN-2 of this
section (natural gas from producers and natural gas processing
plants from local production, or natural gas that was received as a
liquid, vaporized and delivered, and any other source that bypassed
the city gate). (Mscf per year)
EFz = Fuel-specific CO2 emission factor (MT
CO2/Mscf)
(4) Calculate the total CO2 emissions that would result
from the complete combustion or oxidation of the annual supply of
natural gas to end-users that receive a supply less than 460,000 Mscf
per year using Equation NN-6 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.033
Where:
CO2 = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to
LDC end-users not covered in paragraph (b)(2) of this section
(metric tons).
CO2i = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas received at
the city gate as calculated in paragraph (a)(1) or (a)(2) of this
section (metric tons).
CO2n = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas that was
received by the LDC directly from sources bypassing the city gate,
and is not otherwise accounted for in Equation NN-1 or NN-2 of this
section, as calculated in paragraph (b)(3)(ii) of this section
(metric tons).
CO2j = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to
transmission pipelines or other LDCs as calculated in paragraph
(b)(1) of this section (metric tons).
CO2k = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to
each end-user that receives a supply equal to or greater than
460,000 Mscf per year as calculated in paragraph (b)(2) of this
section (metric tons).
CO2l = Annual CO2 mass emissions that would
result from the combustion or oxidation of the net change in natural
gas stored by the LDC within the reported year as calculated in
paragraph (b)(3)(i) of this section (metric tons).
(c) * * *
(2) Calculate the total CO2 equivalent emissions that
would result from the combustion or oxidation of fractionated NGLs
supplied less the quantity received from other fractionators using
Equation NN-8 of this section.
* * * * *
CO2 = Annual CO2 mass emissions that would
result from the combustion or oxidation of fractionated NGLs
delivered to customers or on behalf of customers less the quantity
received from other fractionators (metric tons).
* * * * *
0
89. Section 98.404 is amended by:
0
a. Revising paragraphs (a)(5) introductory text, (a)(7), (a)(8)
introductory text, and (a)(8)(ii).
0
b. Adding paragraph (a)(8)(iii).
0
c. Revising paragraphs (a)(9), (c)(2), (d)(1), and (d)(2).
0
d. Adding paragraph (d)(3).
Sec. 98.404 Monitoring and QA/QC requirements.
(a) * * *
(5) For an LDC using Equation NN-1 or NN-2 of this subpart, the
point(s) of measurement for the natural gas volume received shall be
the LDC city gate meter(s).
* * * * *
(7) An LDC using Equation NN-4 of this subpart shall measure
natural gas at the end-user's meter(s). Where an end-user is known to
have more than one meter located at their facility, the reporter shall
measure the natural gas at each meter and sum the annual volume
delivered to all meters located at the end-user's facility to determine
the total volume delivered to the end-user. Otherwise, the reporter
shall consider the total annual volume delivered through each single
meter at a single particular location to be the volume delivered to an
individual end-user.
(8) An LDC using Equation NN-5a and/or NN-5b of this subpart shall
measure natural gas as follows:
* * * * *
(ii) Fuel2 shall be measured at the meters used for
measuring on-system storage withdrawals and/or LNG vaporization
injection.
(iii) Fuelz shall be measured using established business
practices.
(9) An LDC shall measure all natural gas under the following
standard industry temperature and pressure conditions: Cubic foot of
gas at a temperature of 60 degrees Fahrenheit and at an absolute
pressure of one atmosphere.
* * * * *
(c) * * *
(2) When a reporter used the default EF provided in this section to
calculate Equation NN-2, NN-3, NN-4, NN-5a, NN-5b, or NN-7 of this
subpart, the
[[Page 19873]]
appropriate value shall be taken from Table NN-2 of this subpart.
* * * * *
(d) * * *
(1) Equipment used to measure quantities in Equations NN-1, NN-2,
NN-5a and NN-5b of this subpart shall be calibrated prior to its first
use for reporting under this subpart, using a suitable standard method
published by a consensus based standards organization or according to
the equipment manufacturer's directions.
(2) Equipment used to measure quantities in Equations NN-1, NN-2,
NN-5a, and NN-5b of this subpart shall be recalibrated at the frequency
specified by the standard method used or by the manufacturer's
directions.
(3) Equipment used to measure quantities in Equations NN-3 and NN-4
of this subpart shall be recalibrated at the frequency commonly used
within the industry.
0
90. Section 98.405 is amended by removing and reserving paragraph
(c)(3).
0
91. Section 98.406 is amended by:
0
a. Revising paragraph (a)(4).
0
b. Revising paragraphs (a)(7), (b)(2), and (b)(3).
0
c. Removing and reserving paragraph (b)(4).
0
d. Revising paragraphs (b)(5), (b)(7), (b)(9), and (b)(12) introductory
text.
Sec. 98.406 Data reporting requirements.
(a) * * *
(4) Annual quantities (in barrels) of y-grade, o-grade, and other
bulk NGLs:
(i) Received.
(ii) Supplied to downstream users that are not fractionated by the
reporter.
* * * * *
(7) Annual CO2 mass emissions (metric tons) that would
result from the combustion or oxidation of fractionated NGLs supplied
less the quantity received from other fractionators, calculated in
accordance with Sec. 98.403(c)(2). If the calculated value is
negative, the reporter shall report the value as zero.
* * * * *
(b) * * *
(2) Annual volume in Mscf of natural gas placed into storage or
liquefied and stored (Fuel1 in Equation NN-5a).
(3) Annual volume in Mscf of natural gas withdrawn from on-system
storage and annual volume in Mscf of vaporized liquefied natural gas
(LNG) withdrawn from storage for delivery on the distribution system
(Fuel2 in Equation NN-5a).
(4) [Reserved]
(5) Annual volume in Mscf of natural gas that bypassed the city
gate(s) and was supplied through the LDC distribution system. This
includes natural gas from producers and natural gas processing plants
from local production, or natural gas that was vaporized upon receipt
and delivered, and any other source that bypassed the city gate
(Fuelz in Equation NN-5b).
* * * * *
(7) Annual volume in Mscf of natural gas delivered by the LDC to
each end-user facility that received from the LDC deliveries equal to
or greater than 460,000 Mscf during the calendar year, if known;
otherwise, report the annual volume in Mscf of natural gas delivered by
the LDC to each meter registering supply equal to or greater than
460,000 Mscf during the calendar year.
* * * * *
(9) Annual CO2 emissions (metric tons) that would result
from the complete combustion or oxidation of the annual supply of
natural gas to end-users registering less than 460,000 Mscf, calculated
in accordance with Sec. 98.403(b)(4). If the calculated value is
negative, the reporter shall report the value as zero.
* * * * *
(12) The customer name, address, and meter number of each end-user
reported in paragraph (b)(7) of this section. Additionally, report
whether the quantity of natural gas reported in paragraph (b)(7) of
this section is the total quantity delivered to the end-user, or the
quantity delivered to a specific meter.
* * * * *
0
92. Section 98.407 is amended by revising the introductory text to read
as follows:
Sec. 98.407 Records that must be retained.
In addition to the information required by Sec. 98.3(g), the
reporter shall retain the following records:
* * * * *
0
93. Tables NN-1 and NN-2 to subpart NN are revised to read as follows:
Table NN-1 to Subpart NN of Part 98--Default Factors for Calculation
Methodology 1 of This Subpart
------------------------------------------------------------------------
Default CO2
Default higher emission
Fuel heating value\1\ factor (kg CO2/
MMBtu)
------------------------------------------------------------------------
Natural Gas....................... 1.026 MMBtu/Mscf.... 53.06
Propane........................... 3.84 MMBtu/bbl...... 62.87
Normal butane..................... 4.34 MMBtu/bbl...... 64.77
Ethane............................ 2.85 MMBtu/bbl...... 59.60
Isobutane......................... 4.16 MMBtu/bbl...... 64.94
Pentanes plus..................... 4.62 MMBtu/bbl...... 70.02
------------------------------------------------------------------------
\1\ Conditions for higher heating values presented in MMBtu/bbl are
60[deg]F and saturation pressure.
Table NN-2 to Subpart NN of Part 98--Default Values for Calculation
Methodology 2 of This Subpart
------------------------------------------------------------------------
Default CO2
emission value
Fuel Unit (MT CO2/Unit)\
1\
------------------------------------------------------------------------
Natural Gas....................... Mscf................ 0.0544
Propane........................... Barrel.............. 0.241
Normal butane..................... Barrel.............. 0.281
Ethane............................ Barrel.............. 0.170
Isobutane......................... Barrel.............. 0.270
Pentanes plus..................... Barrel.............. 0.324
------------------------------------------------------------------------
\1\ Conditions for emission value presented in MT CO2/bbl are 60[deg]F
and saturation pressure.
[[Page 19874]]
Subpart PP--[AMENDED]
0
94. Section 98.423 is amended by revising paragraph (a)(3)(i)
introductory text to read as follows:
Sec. 98.423 Calculating CO2 supply.
(a) * * *
(3) * * *
(i) For facilities with production process units or production
wells that capture or extract a CO2 stream and either
measure it after segregation or do not segregate the flow, calculate
the total CO2 supplied in accordance with Equation PP-3a.
* * * * *
0
95. Section 98.426 is amended by revising paragraphs (b)(4)(i),
(b)(4)(ii), (f)(10), and (f)(11) to read as follows:
Sec. 98.426 Data reporting requirements.
* * * * *
(b) * * *
(4) * * *
(i) Quarterly density of the CO2 stream in metric tons
per standard cubic meter if you report the concentration of the
CO2 stream in paragraph (b)(3) of this section in weight
percent.
(ii) Quarterly density of CO2 in metric tons per
standard cubic meter if you report the concentration of the
CO2 stream in paragraph (b)(3) of this section in volume
percent.
* * * * *
(f) * * *
(10) Injection of CO2 for enhanced oil and natural gas
recovery that is covered by subpart UU of this part.
(11) Geologic sequestration of carbon dioxide that is covered by
subpart RR of this part.
* * * * *
Subpart QQ--[AMENDED]
0
96. Section 98.433 is amended by revising the parameter ``St'' of
Equation QQ-1 and Equation QQ-2 to read as follows:
Sec. 98.433 Calculating GHG contained in pre-charged equipment or
closed-cell foams.
(a) * * *
* * * * *
St = Mass of fluorinated GHG per unit of equipment type t
or foam type t (charge per piece of equipment, kg) or density of
fluorinated GHG in foam (charge per cubic foot of foam, kg per cubic
foot).
* * * * *
(b) * * *
* * * * *
St = Mass in CO2e of the fluorinated GHGs per
unit of equipment type t or foam type t (charge per piece of
equipment, kg) or density of fluorinated GHG in foam
(CO2e per cubic foot of foam, kg CO2e per
cubic foot).
* * * * *
0
97. Section 98.434 is amended by revising paragraph (b) to read as
follows:
Sec. 98.434 Monitoring and QA/QC requirements.
* * * * *
(b) The inputs to the annual submission must be reviewed against
the import or export transaction records to ensure that the information
submitted to EPA is being accurately transcribed as the correct
chemical or blend in the correct pre-charged equipment or closed-cell
foam in the correct quantities and units.
0
98. Section 98.436 is amended by:
0
a. Revising paragraphs (a)(3), (a)(4), (a)(6)(ii), (a)(6)(iii), (b)(3),
(b)(4), (b)(6)(ii), and (b)(6)(iii).
Removing and reserving paragraphs (a)(5), (a)(6)(iv), (b)(5), and
(b)(6)(iv).
Sec. 98.436 Data reporting requirements.
(a) * * *
(3) For closed-cell foams that are imported inside of equipment,
the identity of the fluorinated GHG contained in the foam, the mass of
the fluorinated GHG contained in the foam in each piece of equipment,
and the number of pieces of equipment imported with each unique
combination of mass and identity of fluorinated GHG within the closed-
cell foams.
(4) For closed cell-foams that are not imported inside of
equipment, the identity of the fluorinated GHG in the foam, the density
of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and
the volume of foam imported (cubic feet) for each type of closed-cell
foam with a unique combination of fluorinated GHG density and identity.
(5) [Reserved]
(6) * * *
(ii) For closed-cell foams that are imported inside of equipment,
the mass of the fluorinated GHGs in CO2e contained in the
foam in each piece of equipment and the number of pieces of equipment
imported for each equipment type.
(iii) For closed-cell foams that are not imported inside of
equipment, the density in CO2e of the fluorinated GHGs in
the foam (kg CO2e/cubic foot) and the volume of foam
imported (cubic feet) for each type of closed-cell foam.
(iv) [Reserved]
* * * * *
(b) * * *
(3) For closed-cell foams that are exported inside of equipment,
the identity of the fluorinated GHG contained in the foam in each piece
of equipment, the mass of the fluorinated GHG contained in the foam in
each piece of equipment, and the number of pieces of equipment exported
with each unique combination of mass and identity of fluorinated GHG
within the closed-cell foams.
(4) For closed-cell foams that are not exported inside of
equipment, the identity of the fluorinated GHG in the foam, the density
of the fluorinated GHG in the foam (kg fluorinated GHG/cubic foot), and
the volume of foam exported (cubic feet) for each type of closed-cell
foam with a unique combination of fluorinated GHG density and identity.
(5) [Reserved]
(6) * * *
(ii) For closed-cell foams that are exported inside of equipment,
the mass of the fluorinated GHGs in CO2e contained in the
foam in each piece of equipment and the number of pieces of equipment
imported for each equipment type.
(iii) For closed-cell foams that are not exported inside of
equipment, the density in CO2e of the fluorinated GHGs in
the foam (kg CO2 e/cubic foot) and the volume of foam
imported (cubic feet) for each type of closed-cell foam.
(iv) [Reserved]
* * * * *
0
99. Section 98.438 is amended by revising the definitions for ``Closed-
cell foam'' and ``Pre-charged electrical equipment component'' to read
as follows:
Sec. 98.438 Definitions.
* * * * *
Closed-cell foam means any foam product, excluding packaging foam,
that is constructed with a closed-cell structure and a blowing agent
containing a fluorinated GHG. Closed-cell foams include but are not
limited to polyurethane (PU) foam contained in equipment, PU continuous
and discontinuous panel foam, PU one component foam, PU spray foam,
extruded polystyrene (XPS) boardstock foam, and XPS sheet foam.
Packaging foam means foam used exclusively during shipment or storage
to temporarily enclose items.
* * * * *
Pre-charged electrical equipment component means any portion of
electrical equipment that is charged with a fluorinated greenhouse gas
prior to sale or distribution or offer for sale or distribution in
interstate commerce.
Subpart RR--[AMENDED]
0
100. Section 98.443 is amended by:
0
a. Revising the parameter ``Sr,p'' of Equation RR-2 at
paragraph (a)(2).
[[Page 19875]]
0
b. Revising paragraph (d)(3) introductory text.
0
c. Revising the parameter ``CO2FI'' of Equation RR-12.
Sec. 98.443 Calculating CO2 geologic sequestration.
* * * * *
(a) * * *
(2) * * *
* * * * *
Sr,p = Quarterly volume of contents in containers r
redelivered to another facility without being injected into your
well in quarter p (standard cubic meters).
* * * * *
(d) * * *
(3) To aggregate production data, you must sum the mass of all of
the CO2 separated at each gas-liquid separator in accordance
with the procedure specified in Equation RR-9 of this section. You must
assume that the total CO2 measured at the separator(s)
represents a percentage of the total CO2 produced. In order
to account for the percentage of CO2 produced that is
estimated to remain with the produced oil or other fluid, you must
multiply the quarterly mass of CO2 measured at the
separator(s) by a percentage estimated using a methodology in your
approved MRV plan. If fluids containing CO2 from injection
wells covered under this source category are produced and not processed
through a gas-liquid separator, the concentration of CO2 in
the produced fluids must be measured at a flow meter located prior to
reinjection or reuse using methods in Sec. 98.444(f)(1). The
considerations you intend to use to calculate CO2 from
produced fluids for the mass balance equation must be described in your
approved MRV plan in accordance with Sec. 98.448(a)(5).
* * * * *
(f) * * *
(2) * * *
* * * * *
CO2FI = Total annual CO2 mass emitted (metric
tons) from equipment leaks and vented emissions of CO2
from equipment located on the surface between the flow meter used to
measure injection quantity and the injection wellhead, for which a
calculation procedure is provided in subpart W of this part.
0
101. Section 98.446 is amended by revising paragraph (b)(5) to read as
follows:
Sec. 98.446 Data reporting requirements.
* * * * *
(b) * * *
(5) The standard or method used to calculate each value in
paragraphs (b)(1), (b)(2), and (b)(3) of this section.
* * * * *
Subpart SS--[AMENDED]
0
102. Section 98.453 is amended by:
0
a. Revising paragraph (d).
0
b. Revising paragraph (h).
0
c. Revising the parameter ``MF'' of Equation SS-6.
Sec. 98.453 Calculating GHG emissions.
* * * * *
(d) Estimate the mass of SF6 or PFCs disbursed to
customers in new equipment or cylinders over the period p by monitoring
the mass flow of the SF6 or PFCs into the new equipment or
cylinders using a flowmeter, or by weighing containers before and after
gas from containers is used to fill equipment or cylinders, or by using
the nameplate capacity of the equipment.
* * * * *
(h) If the mass of SF6 or the PFC disbursed to customers
in new equipment or cylinders over the period p is determined by using
the nameplate capacity, or by using the nameplate capacity of the
equipment and calculating the partial shipping charge, use the methods
in either paragraph (h)(1) or (h)(2) of this section.
(1) Determine the equipment's actual nameplate capacity, by
measuring the nameplate capacities of a representative sample of each
make and model and calculating the mean value for each make and model
as specified at Sec. 98.454(f).
(2) If equipment is shipped with a partial charge, calculate the
partial shipping charge by multiplying the nameplate capacity of the
equipment by the ratio of the densities of the partial charge to the
full charge.
(i) * * *
* * * * *
MF = The total annual mass of the SF6 or PFCs, in pounds,
used to fill equipment during equipment installation at electric
transmission or distribution facilities.
* * * * *
0
103. Section 98.456 is amended by revising paragraphs (m), (o), and (p)
to read as follows:
Sec. 98.456 Data reporting requirements.
* * * * *
(m) The values for EFci of Equation SS-5 of this subpart
for each hose and valve combination and the associated valve fitting
sizes and hose diameters.
* * * * *
(o) If the mass of SF6 or the PFC disbursed to customers
in new equipment over the period p is determined according to the
methods required in Sec. 98.453(h), report the mean value of nameplate
capacity in pounds for each make, model, and group of conditions.
(p) If the mass of SF6 or the PFC disbursed to customers
in new equipment over the period p is determined according to the
methods required in Sec. 98.453(h), report the number of samples and
the upper and lower bounds on the 95 percent confidence interval for
each make, model, and group of conditions.
* * * * *
Subpart TT--[AMENDED]
0
104. Section 98.460 is amended by revising paragraph (c)(2)(xiii) to
read as follows:
Sec. 98.460 Definition of the source category.
* * * * *
(c) * * *
(2) * * *
(xiii) Other waste material that has a DOC value of 0.3 weight
percent (on a wet basis) or less. DOC value must be determined using a
60-day anaerobic biodegradation test procedure identified in Sec.
98.464(b)(4)(i).
* * * * *
0
105. Section 98.463 is amended by:
0
a. Revising the parameter ``DOCF'' of Equation TT-1.
0
b. Removing the parameter ``Fx'' of Equation TT-1 and adding
in its place the parameter ``F''.
0
c. Revising Equation TT-4b.
0
d. Revising the parameter ``OX'' of Equation TT-6.
Sec. 98.463 Calculating GHG emissions.
(a) * * *
(1) * * *
* * * * *
DOCF = Fraction of DOC dissimilated (fraction); use the
default value of 0.5. If measured values of DOC are available using
the 60-day anaerobic biodegradation test procedure identified in
98.464(b)(4)(i), use a default value of 1.0.
* * * * *
F = Fraction by volume of CH4 in landfill gas (fraction,
dry basis, corrected to 0% oxygen). If you have a gas collection
system, use the annual average CH4 concentration from
measurement data for the current reporting year; otherwise, use the
default value of 0.5.
* * * * *
(2) * * *
(ii) * * *
(C) * * *
* * * * *
[[Page 19876]]
[GRAPHIC] [TIFF OMITTED] TP02AP13.010
* * * * *
(b) * * *
(1) * * *
* * * * *
OX = Oxidation fraction from Table HH-4 of subpart HH of this part.
* * * * *
0
106. Section 98.464 is amended by:
0
a. Revising paragraph (b) introductory text.
0
b. Revising Equation TT-7.
0
c. Removing the parameters ``DOCF'',
``MCDcontrol'', and ``MCcontrol'' of Equation TT-
7.
0
d. Revising paragraph (c).
Sec. 98.464 Monitoring and QA/QC requirements.
* * * * *
(b) For each waste stream placed in the landfill during the
reporting year for which you choose to determine volatile solids
concentration and/or a waste stream-specific DOCX, you must
collect and test a representative sample of that waste stream using the
methods specified in paragraphs (b)(1) through (b)(4) of this section,
as applicable.
* * * * *
(4) * * *
(i) * * *
(E) * * *
[GRAPHIC] [TIFF OMITTED] TP02AP13.011
Where:
DOCX = Degradable organic content of the waste stream in
Year X (weight fraction, wet basis)
MCDsample,x = Mass of carbon degraded in the waste stream
sample in Year X as determined in paragraph (b)(4)(i)(C) of this
section [milligrams (mg)].
Msample,x = Mass of waste stream sample used in the
anaerobic degradation test in Year X (mg, wet basis).
* * * * *
(c) For each waste stream that was historically managed in the
landfill but was not received during the first reporting year for which
you choose to determine volatile solids concentration and/or a waste
stream-specific DOCX, you must determine volatile solids
concentration or DOCX of the waste stream as initially
placed in the landfill using the methods specified in paragraph (c)(1)
or (c)(2) of this section, as applicable.
(1) If you can identify a similar waste stream to the waste stream
that was historically managed in the landfill, you must determine the
volatile solids concentration or DOCX of the similar waste
stream using the applicable procedures in paragraphs (b)(1) through
(b)(4) of this section.
(2) If you cannot identify a similar waste stream to the waste
stream that was historically managed in the landfill, you may determine
the volatile solids concentration or DOCX of the
historically managed waste stream using process knowledge. You must
document the basis for the volatile solids concentration or
DOCX value as determined through process knowledge.
* * * * *
0
107. Section 98.466 is amended by:
0
a. Revising paragraph (b)(1).
0
b. Adding paragraph (b)(5).
0
c. Revising paragraph (c) introductory text.
0
d. Removing and reserving paragraph (c)(1).
0
e. Revising paragraphs (c)(2), (c)(3) introductory text, and (c)(4)
introductory text.
0
f. Adding paragraph (c)(5).
0
g. Revising paragraph (d)(3).
0
h. Revising paragraph (h).
Sec. 98.466 Data reporting requirements.
* * * * *
(b) * * *
(1) The number of waste steams (including ``Other Industrial Solid
Waste (not otherwise listed)'' and ``Inerts'') for which Equation TT-1
of this subpart is used to calculate modeled CH4 generation.
* * * * *
(5) For each waste stream, the decay rate (k) value used in the
calculations.
(c) Report the following historical waste information:
(1) [Reserved]
(2) For each waste stream identified in paragraph (b) of this
section, the method(s) for estimating historical waste disposal
quantities and the range of years for which each method applies.
(3) For each waste stream identified in paragraph (b) of this
section for which Equation TT-2 of this subpart is used, provide:
* * * * *
(4) If Equation TT-4a of this subpart is used, provide:
* * * * *
(5) If Equation TT-4b of this subpart is used, provide:
(i) WIP (i.e., the quantity of waste in-place at the start of the
reporting year from design drawings or engineering estimates (metric
tons) or, for closed landfills for which waste in-place quantities are
not available, the landfill's design capacity).
(ii) The cumulative quantity of waste placed in the landfill for
the years for which disposal quantities are available from company
record or from Equation TT-3 of this part.
(iii) YrLast.
(iv) YrOpen.
(v) NYrData.
(d) * * *
(3) For each waste stream, the degradable organic carbon
(DOCX) value (mass fraction) for the specified year and an
indication as to whether this was the default value from Table TT-1 to
this subpart, a measured value using a 60-day anaerobic biodegradation
test as specified in Sec. 98.464(b)(4)(i), or a value based on total
and volatile solids measurements as specified in Sec.
98.464(b)(4)(ii). If DOCx was determined by a 60-day
anaerobic biodegradation test, specify the test method used.
* * * * *
(h) For landfills with gas collection systems, in addition to the
reporting requirements in paragraphs (a) through (f) of this section,
provide:
(1) The annual methane generation, adjusted for oxidation,
calculated using Equation TT-6 of this subpart, reported in metric tons
CH4;
(2) The oxidation factor used in Equation TT-6 of this subpart; and
(3) All information required under 40 CFR 98.346(i)(1) through
(i)(7) and 40 CFR 98.346(i)(9) through (i)(12).
0
108. Section 98.467 is revised to read as follows:
[[Page 19877]]
Sec. 98.467 Records that must be retained.
In addition to the information required by Sec. 98.3(g), you must
retain the calibration records for all monitoring equipment, including
the method or manufacturer's specification used for calibration, and
all measurement data used for the purposes of paragraphs Sec.
98.460(c)(2)(xii) or (c)(2)(xiii) or used to determine waste stream-
specific DOCX values for use in Equation TT-1 of this
subpart.
0
109. Table TT-1 to Subpart TT is amended by:
0
a. Revising the first four entries.
0
b. Adding a new entry following ``Construction and Demolition''.
Table TT-1 to Subpart TT--Default DOC and Decay Rate Values for Industrial Waste Landfills
----------------------------------------------------------------------------------------------------------------
DOC (weight k [dry k [moderate k [wet
Industry/waste type fraction, climate\a\] climate\a\] climate\a\]
wet basis) (yr\ -1\) (yr \-1\) (yr \-1\)
----------------------------------------------------------------------------------------------------------------
Food Processing (other than sludge)......................... 0.22 0.06 0.12 0.18
Pulp and Paper (other than sludge).......................... 0.20 0.02 0.03 0.04
Wood and Wood Product (other than sludge)................... 0.43 0.02 0.03 0.04
Construction and Demolition................................. 0.08 0.02 0.03 0.04
Industrial Sludge........................................... 0.09 0.02 0.04 0.06
* * * * * * * * *
----------------------------------------------------------------------------------------------------------------
\a\ The applicable climate classification is determined based on the annual rainfall plus the recirculated
leachate application rate. Recirculated leachate application rate (in inches/year) is the total volume of
leachate recirculated from company records or engineering estimates and applied to the landfill divided by the
area of the portion of the landfill containing waste [with appropriate unit conversions].
(1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year
(2) Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive)
(3) Wet climate = precipitation plus recirculated leachate greater than 40 inches/year
Alternatively, landfills that use leachate recirculation can elect to use the k value for wet climate rather
than calculating the recirculated leachate rate.
\(1)\ Dry climate = precipitation plus recirculated leachate less than 20 inches/year.
\(2)\ Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive).
\(3)\ Wet climate = precipitation plus recirculated leachate greater than 40 inches/year.
Subpart UU--[AMENDED]
0
110. Section 98.473 is amended by revising:
0
a. The parameter ``D'' of Equation UU-2 in paragraph (a)(2).
0
b. The parameter ``Sr,p'' of Equation UU-2 in paragraph
(b)(2).
Sec. 98.473 Calculating CO2 received.
(a) * * *
(2) * * *
* * * * *
D = Density of CO2 at standard conditions (metric tons
per standard cubic meter): 0.0018682.
* * * * *
(b) * * *
(2) * * *
* * * * *
Sr,p = Quarterly volume of contents in containers r that
is redelivered to another facility without being injected into your
well in quarter p (standard cubic meters).
* * * * *
0
111. Section 98.476 is amended by:
0
a. Revising paragraph (b)(5).
0
b. Adding paragraph (e).
Sec. 98.476 Data reporting requirements.
* * * * *
(b) * * *
(5) The standard or method used to calculate each value in
paragraphs (b)(1), (b)(2), and (b)(3) of this section.
* * * * *
(e) Report the following:
(1) Whether the facility received a Research and Development
project exemption from reporting under 40 CFR part 98, subpart RR, for
this reporting year. If you received an exemption, report the start and
end dates of the exemption approved by EPA.
(2) Whether the facility includes a well or group of wells where a
CO2 stream was injected into subsurface geologic formations
to enhance the recovery of oil during this reporting year.
(3) Whether the facility includes a well or group of wells where a
CO2 stream was injected into subsurface geologic formations
to enhance the recovery of natural gas during this reporting year.
(4) Whether the facility includes a well or group of wells where a
CO2 stream was injected into subsurface geologic formations
for acid gas disposal during this reporting year.
(5) Whether the facility includes a well or group of wells where a
CO2 stream was injected for a purpose other than those
listed in paragraphs (e)(1) through (4) of this section. If you
injected CO2 for another purpose, report the purpose of the
injection.
[FR Doc. 2013-06093 Filed 4-1-13; 8:45 am]
BILLING CODE 6560-50-P