[Federal Register Volume 77, Number 13 (Friday, January 20, 2012)]
[Notices]
[Page 2989]
[FR Doc No: 2012-1111]

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DEPARTMENT OF HOMELAND SECURITY

Federal Emergency Management Agency

[Internal Agency Docket No. FEMA-4051-DR; Docket ID FEMA-2011-0001]

Massachusetts; Major Disaster and Related Determinations

AGENCY: Federal Emergency Management Agency, DHS.

ACTION: Notice.

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SUMMARY: This is a notice of the Presidential declaration of a major
disaster for the Commonwealth of Massachusetts (FEMA-4051-DR), dated
January 6, 2012, and related determinations.

DATES: Effective Date: January 6, 2012.

FOR FURTHER INFORMATION CONTACT: Peggy Miller, Office of Response and
Recovery, Federal Emergency Management Agency, 500 C Street SW.,
Washington, DC 20472,<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION: Notice is hereby given that, in a letter
dated January 6, 2012, the President issued a major disaster
declaration under the authority of the Robert T. Stafford Disaster
Relief and Emergency Assistance Act, 42 U.S.C. 5121 et seq. (the
``Stafford Act''), as follows:

    I have determined that the damage in certain areas of the
Commonwealth of Massachusetts resulting from a severe storm and
snowstorm during the period of October 29-30, 2011, is of sufficient
severity and magnitude to warrant a major disaster declaration under
the Robert T. Stafford Disaster Relief and Emergency Assistance Act,
42 U.S.C. 5121 et seq. (the ``Stafford Act''). Therefore, I declare
that such a major disaster exists in the Commonwealth of
Massachusetts.
    In order to provide Federal assistance, you are hereby
authorized to allocate from funds available for these purposes such
amounts as you find necessary for Federal disaster assistance and
administrative expenses.
    You are authorized to provide Public Assistance in the
designated areas and Hazard Mitigation throughout the Commonwealth.
You are further authorized to provide snow assistance under the
Public Assistance program in the designated areas for any continuous
48-hour period during or proximate to the incident period. You may
extend the period of assistance, as warranted. This assistance
excludes regular time costs for the sub-grantees' regular employees.
    Consistent with the requirement that Federal assistance is
supplemental, any Federal funds provided under the Stafford Act for
Public Assistance and Hazard Mitigation will be limited to 75
percent of the total eligible costs.
    Further, you are authorized to make changes to this declaration
for the approved assistance to the extent allowable under the
Stafford Act.

    The Federal Emergency Management Agency (FEMA) hereby gives notice
that pursuant to the authority vested in the Administrator, under
Executive Order 12148, as amended, Mark H. Landry, of FEMA is appointed
to act as the Federal Coordinating Officer for this major disaster.
    The following areas of the Commonwealth of Massachusetts have been
designated as adversely affected by this major disaster:

    Berkshire, Franklin, Hampden, Hampshire, Middlesex, and
Worcester Counties for Public Assistance.
    Berkshire, Franklin, Hampden, and Hampshire Counties for snow
assistance under the Public Assistance program for any continuous
48-hour period during or proximate to the incident period.
    All counties within the Commonwealth of Massachusetts are
eligible to apply for assistance under the Hazard Mitigation Grant
Program.

The following Catalog of Federal Domestic Assistance Numbers (CFDA)
are to be used for reporting and drawing funds: 97.030, Community
Disaster Loans; 97.031, Cora Brown Fund; 97.032, Crisis Counseling;
97.033, Disaster Legal Services; 97.034, Disaster Unemployment
Assistance (DUA); 97.046, Fire Management Assistance Grant; 97.048,
Disaster Housing Assistance to Individuals and Households in
Presidentially Declared Disaster Areas; 97.049, Presidentially
Declared Disaster Assistance--Disaster Housing Operations for
Individuals and Households; 97.050, Presidentially Declared Disaster
Assistance to Individuals and Households--Other Needs; 97.036,
Disaster Grants--Public Assistance (Presidentially Declared
Disasters); 97.039, Hazard Mitigation Grant.

W. Craig Fugate,
Administrator, Federal Emergency Management Agency.
[FR Doc. 2012-1111 Filed 1-19-12; 8:45 am]
BILLING CODE 9111-23-P


[Federal Register: April 19, 2006 (Volume 71, Number 75)]
[Notices]
[Page 20090-20092]
[DOCID:fr19ap06-75]

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ENVIRONMENTAL PROTECTION AGENCY

[EPA-HQ-OPP-2006-0156; FRL-8064-5]

Alkylbenzene Sulfonates Risk Assessment and Preliminary Risk
Reduction Options; Notice of Availability

AGENCY: Environmental Protection Agency (EPA).

ACTION: Notice.

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SUMMARY: This notice announces the availability of EPA's risk
assessment, preliminary risk reduction options, and related documents
for the pesticide alkylbenzene sulfonates which

encompasses sodium dodecylbenzene sulfonate; dodecylbenzene sulfonic
acid; and benzenesulfonic acid, C10-C16 alkyl derivatives, and opens a
public comment period on these documents. The public also is encouraged
to suggest risk management ideas or proposals to address the risks
identified. EPA is developing a Reregistration Eligibility Decision
(RED) for alkylbenzene sulfonates through a modified, 4-Phase public
participation process that the Agency uses to involve the public in
developing pesticide reregistration and tolerance reassessment
decisions. This is Phase 3 of the 4-Phase Process. Through these
programs, EPA is ensuring that all pesticides meet current health and
safety standards.

DATES Comments must be received on or before June 19, 2006.

ADDRESSES: Submit your comments, identified by docket identification
(ID) number EPA-HQ-OPP-2006-0156, by one of the following methods:
     Federal eRulemaking Portal: http://www.regulations.gov.

Follow the on-line instructions for submitting comments.
     Mail: Office of Pesticide Programs (OPP) Regulatory Public
Docket (7502C), Environmental Protection Agency, 1200 Pennsylvania
Ave., NW., Washington, DC 20460-0001.
     Hand Delivery: OPP Regulatory Public Docket, Environmental
Protection Agency, Rm. 119, Crystal Mall 2, 1801 S. Bell St.,
Arlington, VA. Deliveries are only accepted during the Docket's normal
hours of operation (8:30 a.m. to 4 p.m., Monday through Friday,
excluding legal holidays). Special arrangements should be made for
deliveries of boxed information. The Docket telephone number is (703)
305-5805.
     Important Note: OPP will be moving to a new location the
first week of May 2006. As a result, from Friday, April 28 to Friday,
May 5, 2006, the OPP Regulatory Public Docket will NOT be accepting any
deliveries at the Crystal Mall 2 address and this facility
will be closed to the public. Beginning on May 8, 2006, the OPP
Regulatory Public Docket will reopen at 8:30 a.m. and deliveries will
be accepted in Rm. S-4400, One Potomac Yard (South Building), 2777 S.
Crystal Drive, Arlington, VA 22202. The mail code for the mailing
address will change to (7502P), but will otherwise remain the same. The
OPP Regulatory Public Docket telephone number and hours of operation
will remain the same after the move.
    Instructions: Direct your comments to docket ID number EPA-HQ-OPP-
2006-0156. EPA's policy is that all comments received will be included
in the docket without change and may be made available on-line 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. Do not submit information that you
consider to be CBI or otherwise protected through regulations.gov or e-
mail. The Federal regulations.gov website is an ``anonymous access''
system, which means EPA will not know your identity or contact
information unless you provide it in the body of your comment. If you
send an e-mail comment directly to EPA without going through
regulations.gov, your e-mail address will be automatically captured and
included as part of the comment that is placed in the docket and made
available on the Internet. If you submit an electronic comment, 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 EPA
cannot read your comment due to technical difficulties and cannot
contact you for clarification, 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 docket 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, is not placed on the Internet and will be publicly available
only in hard copy form. Publicly available docket materials are
available in the electronic docket at http://www.regulations.gov, or,

if only available in hard copy, at the OPP Regulatory Public Docket at
the location identified under ``Delivery'' and ``Important Note.'' The
hours of operation for this docket facility are from 8:30 a.m. to 4
p.m., Monday through Friday, excluding legal holidays. The docket
telephone number is<PHONE_NUMBER>.

FOR FURTHER INFORMATION CONTACT: Heather Garvie, Antimicrobials
Division, (7510C), Office of Pesticide Programs, Environmental
Protection Agency, 1200 Pennsylvania Ave., NW., Washington, DC 20460-
0001; telephone number:<PHONE_NUMBER>; fax number:<PHONE_NUMBER>; e-
mail address<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:

I. General Information

A. Does this Action Apply to Me?

    This action is directed to the public in general, and may be of
interest to a wide range of stakeholders including environmental, human
health, and agricultural advocates; the chemical industry; pesticide
users; and members of the public interested in the sale, distribution,
or use of pesticides. Since others also may be interested, the Agency
has not attempted to describe all the specific entities that may be
affected by this action. If you have any questions regarding the
applicability of this action to a particular entity, consult the person
listed under FOR FURTHER INFORMATION CONTACT.

B. What Should I Consider as I Prepare My Comments for EPA?

    1. Submitting CBI. Do not submit this information to EPA through
http://www.regulations.gov or e-mail. Clearly mark the part or all of the

information that you claim to be CBI. For CBI information in a disk or
CD ROM that you mail to 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 so marked will not be disclosed except in accordance with
procedures set forth in 40 CFR part 2.
    2. Tips for preparing your comments. When submitting comments,
remember to:
    i. Identify the document by docket number and other identifying
information (subject heading, Federal Register date and page number).
    ii. Follow directions. The agency may ask you to respond to
specific questions or organize comments by referencing a Code of
Federal Regulations (CFR) part or section number.
    iii. Explain why you agree or disagree; suggest alternatives and
substitute language for your requested changes.
    iv. Describe any assumptions and provide any technical information
and/or data that you used.
    v. If you estimate potential costs or burdens, explain how you
arrived at your estimate in sufficient detail to allow for it to be
reproduced.
    vi. Provide specific examples to illustrate your concerns, and
suggest alternatives.

    vii. Explain your views as clearly as possible, avoiding the use of
profanity or personal threats.
    viii. Make sure to submit your comments by the comment period
deadline identified.

II. Background

A. What Action is the Agency Taking?

    EPA is releasing for public comment its human health and
environmental fate and effects risk assessment, preliminary risk
reduction options, and related documents for alkylbenzene sulfonates
(encompassing sodium dodecylbenzene sulfonate; dodecylbenzene sulfonic
acid; and benzenesulfonic acid, C10-C16 alkyl derivatives), and
encouraging the public to suggest risk management ideas or proposals.
The alkylbenzene sulfonates are both active and inert ingredients in
pesticide products. As active ingredients, they are currently found in
end-use products as a disinfectant, food-contact sanitizer,
bacteriocide/bacteriostat, microbiocide/microbiostat, fungicide/
fungistat, and virucide. As inert ingredients, they are found in end-
use products, many of which are used in residential settings, and
outdoors in agricultural settings. EPA developed the risk assessment
and preliminary risk reduction options for alkylbenzene sulfonates
through a modified version of its public process for making pesticide
reregistration eligibility and tolerance reassessment decisions.
Through these programs, EPA is ensuring that pesticides meet current
standards under the Federal Insecticide, Fungicide, and Rodenticide Act
(FIFRA) and the Federal Food, Drug, and Cosmetic Act (FFDCA), as
amended by the Food Quality Protection Act of 1996 (FQPA).
    The alkylbenzene sulfonates are both active and inert ingredients
in pesticide products. As active ingredients, they are currently in 23
registered end-use products as a disinfectant, food-contact sanitizer,
bacteriocide/bacteriostat, microbiocide/microbiostat, fungicide/
fungistat, and virucide. Alkylbenzene sulfonates are in cleaners and
sanitizers that are designated for use in agricultural, food handling
and commercial/institutional/industrial settings. Examples of
registered uses for alkylbenzene sulfonates include, but are not
limited to: Application to indoor hard surfaces e.g., urinals, shower
stalls, toilet bowls, etc., food dispensing equipment (e.g., pre-mix
and post-mix vending machines), food contact surfaces (glasses, dishes,
silverware, countertops, etc.), agricultural tools, and fruits and
vegetables (post-harvest). As active ingredients, there are no
residential or outdoor uses currently registered. As inert ingredients,
there are approximately 350 registered end-use products containing
these chemicals. Many of these products are used in residential
settings, and outdoors in agricultural settings. The Agency's risk
assessment identified dietary, residential and occupational risks of
concern for some exposure scenarios. Because limited information is
available for some exposure scenarios conservative assumptions were
sometimes used in the risk assessment. The Agency is interested in
receiving any information that could assist in refining the risk
assessment.
    EPA is providing an opportunity, through this notice, for
interested parties to provide comments and input on the Agency's risk
assessment for alkylbenzene sulfonates. Such comments and input could
address, for example, the availability of additional data to further
refine the risk assessments, such as ecological data to fill data gaps
for aquatic toxicity studies for freshwater fish and invertebrates, or
could address the Agency's risk assessment methodologies and
assumptions as applied to this specific pesticide. Through this notice,
EPA is also releasing for public comment its preliminary risk reduction
options for alkylbenzene sulfonates, and is providing an opportunity
for interested parties to provide risk management proposals or
otherwise comment on risk management.
    EPA seeks to achieve environmental justice, the fair treatment and
meaningful involvement of all people, regardless of race, color,
national origin, or income, in the development, implementation, and
enforcement of environmental laws, regulations, and policies. To help
address potential environmental justice issues, the Agency seeks
information on any groups or segments of the population who, as a
result of their location, cultural practices, or other factors, may
have atypical, unusually high exposure to alkylbenzene sulfonates,
compared to the general population.
    EPA is applying the principles of public participation to all
pesticides undergoing reregistration and tolerance reassessment. The
Agency's Pesticide Tolerance Reassessment and Reregistration; Public
Participation Process, published in the Federal Register on May 14,
2004, (69 FR 26819) (FRL-7357-9) explains that in conducting these
programs, the Agency is tailoring its public participation process to
be commensurate with the level of risk, extent of use, complexity of
the issues, and degree of public concern associated with each
pesticide. For alkylbenzene sulfonates, a modified, 4-Phase process
with one comment period and ample opportunity for public consultation
seems appropriate in view of its refined risk assessment, few complex
issues, and/or other factors. However, if as a result of comments
received during this comment period EPA finds that additional issues
warranting further discussion are raised, the Agency may lengthen the
process and include a second comment period, as needed.
    All comments should be submitted using the methods in ADDRESSES,
and must be received by EPA on or before the closing date. Comments
will become part of the Agency Docket for alkylbenzene sulfonates.
Comments received after the close of the comment period will be marked
``late.'' EPA is not required to consider these late comments.

B. What is the Agency's Authority for Taking this Action?

    Section 4(g)(2) of FIFRA as amended directs that, after submission
of all data concerning a pesticide active ingredient, ``the
Administrator shall determine whether pesticides containing such active
ingredient are eligible for reregistration'' before calling in product
specific data on individual end-use products and either reregistering
products or taking other ``appropriate regulatory action.''
    Section 408(q) of the FFDCA, 21 U.S.C. 346a(q), requires EPA to
review tolerances and exemptions for pesticide residues in effect as of
August 2, 1996, to determine whether the tolerance or exemption meets
the requirements of section 408(b)(2) or (c)(2) of FFDCA. This review
is to be completed by August 3, 2006.

List of Subjects

    Environmental protection, Alkylbenzene sulfonates Pesticides and
pests.

    Dated: April 4, 2006.
Frank Sanders,
Director, Antimicrobials Division, Office of Pesticide Programs.
[FR Doc. E6-5879 Filed 4-18-06; 8:45 am]

BILLING CODE 6560-50-S


[Federal Register: July 13, 2010 (Volume 75, Number 133)]
[Rules and Regulations]
[Page 39787-39789]
[DOCID:fr13jy10-1]

========================================================================
Rules and Regulations
                                                Federal Register
________________________________________________________________________

This section of the FEDERAL REGISTER contains regulatory documents
having general applicability and legal effect, most of which are keyed
to and codified in the Code of Federal Regulations, which is published
under 50 titles pursuant to 44 U.S.C. 1510.

The Code of Federal Regulations is sold by the Superintendent of Documents.
Prices of new books are listed in the first FEDERAL REGISTER issue of each
week.

========================================================================

DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

14 CFR Part 39

[Docket No. FAA-2010-0229; Directorate Identifier 2009-NM-115-AD;
Amendment 39-16356; AD 2010-14-11]
RIN 2120-AA64

Airworthiness Directives; Bombardier, Inc. Model DHC-8-400 Series
Airplanes

AGENCY: Federal Aviation Administration (FAA), Department of
Transportation (DOT).

ACTION: Final rule.

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SUMMARY: We are adopting a new airworthiness directive (AD) for the
products listed above. This AD results from mandatory continuing
airworthiness information (MCAI) originated by an aviation authority of
another country to identify and correct an unsafe condition on an
aviation product. The MCAI describes the unsafe condition as:

    Certain main landing gear components have experienced premature
failure during certification testing. Revision has been made to the
DHC-8-400 Maintenance Requirements Manual, Airworthiness Limitation
Items, to incorporate the revised safe life limits for the main
landing gear lock actuator assembly, retraction actuator assembly
rod end and piston, and the upper bearing in the main landing gear
shock strut assembly. Failure of these components could adversely
affect the structural integrity of the main landing gear.

* * * * *
We are issuing this AD to require actions to correct the unsafe
condition on these products.

DATES: This AD becomes effective August 17, 2010.
    The Director of the Federal Register approved the incorporation by
reference of certain publications listed in this AD as of August 17,
2010.

ADDRESSES: You may examine the AD docket on the Internet at http://
www.regulations.gov or in person at the U.S. Department of
Transportation, Docket Operations, M-30, West Building Ground Floor,
Room W12-140, 1200 New Jersey Avenue, SE., Washington, DC.

FOR FURTHER INFORMATION CONTACT: Craig Yates, Aerospace Engineer,
Airframe and Mechanical Systems Branch, ANE-171, FAA, New York Aircraft
Certification Office, 1600 Stewart Avenue, Suite 410, Westbury, New
York 11590; telephone<PHONE_NUMBER>; fax<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION:

Discussion

    We issued a notice of proposed rulemaking (NPRM) to amend 14 CFR
part 39 to include an AD that would apply to the specified products.
That NPRM was published in the Federal Register on March 17, 2010 (75
FR 12710). That NPRM proposed to correct an unsafe condition for the
specified products. The MCAI states:

    Certain main landing gear components have experienced premature
failure during certification testing. Revision has been made to the
DHC-8-400 Maintenance Requirements Manual, Airworthiness Limitation
Items, to incorporate the revised safe life limits for the main
landing gear lock actuator assembly, retraction actuator assembly
rod end and piston, and the upper bearing in the main landing gear
shock strut assembly. Failure of these components could adversely
affect the structural integrity of the main landing gear.
    This [Canadian airworthiness] directive is issued to ensure safe
operation of the main landing gear during its service life.

The corrective actions include revising the Airworthiness Limitations
section of the Instructions for Continued Airworthiness, replacing the
upper bearing on certain airplanes, and replacing certain rod ends. You
may obtain further information by examining the MCAI in the AD docket.

Comments

    We gave the public the opportunity to participate in developing
this AD. We received no comments on the NPRM or on the determination of
the cost to the public.

Conclusion

    We reviewed the available data and determined that air safety and
the public interest require adopting the AD as proposed.

Differences Between This AD and the MCAI or Service Information

    We have reviewed the MCAI and related service information and, in
general, agree with their substance. But we might have found it
necessary to use different words from those in the MCAI to ensure the
AD is clear for U.S. operators and is enforceable. In making these
changes, we do not intend to differ substantively from the information
provided in the MCAI and related service information.
    We might also have required different actions in this AD from those
in the MCAI in order to follow our FAA policies. Any such differences
are highlighted in a Note within the AD.

Costs of Compliance

    We estimate that this AD will affect 62 products of U.S. registry.
We also estimate that it will take about 22 work-hours per product to
comply with the basic requirements of this AD. The average labor rate
is $85 per work-hour. Required parts will cost about $18,588 per
product. Where the service information lists required parts costs that
are covered under warranty, we have assumed that there will be no
charge for these parts. As we do not control warranty coverage for
affected parties, some parties may incur costs higher than estimated
here. Based on these figures, we estimate the cost of this AD to the
U.S. operators to be $1,268,396, or $20,458 per product.

Authority for This Rulemaking

    Title 49 of the United States Code specifies the FAA's authority to
issue rules on aviation safety. Subtitle I, section 106, describes the
authority of the FAA Administrator. ``Subtitle VII: Aviation
Programs,'' describes in more detail the scope of the Agency's
authority.
    We are issuing this rulemaking under the authority described in
``Subtitle VII, Part A, Subpart III, Section 44701: General
requirements.'' Under that section, Congress charges the FAA with
promoting safe flight of civil aircraft in air commerce by prescribing
regulations for practices, methods, and procedures

the Administrator finds necessary for safety in air commerce. This
regulation is within the scope of that authority because it addresses
an unsafe condition that is likely to exist or develop on products
identified in this rulemaking action.

Regulatory Findings

    We determined that this AD will not have federalism implications
under Executive Order 13132. This AD will not have a substantial direct
effect 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.
    For the reasons discussed above, I certify this AD:
    1. Is not a ``significant regulatory action'' under Executive Order
12866;
    2. Is not a ``significant rule'' under the DOT Regulatory Policies
and Procedures (44 FR 11034, February 26, 1979); and
    3. Will not have a significant economic impact, positive or
negative, on a substantial number of small entities under the criteria
of the Regulatory Flexibility Act.
    We prepared a regulatory evaluation of the estimated costs to
comply with this AD and placed it in the AD docket.

Examining the AD Docket

    You may examine the AD docket on the Internet at http://
www.regulations.gov; or in person at the Docket Operations office
between 9 a.m. and 5 p.m., Monday through Friday, except Federal
holidays. The AD docket contains the NPRM, the regulatory evaluation,
any comments received, and other information. The street address for
the Docket Operations office (telephone<PHONE_NUMBER>) is in the
ADDRESSES section. Comments will be available in the AD docket shortly
after receipt.

List of Subjects in 14 CFR Part 39

    Air transportation, Aircraft, Aviation safety, Incorporation by
reference, Safety.

Adoption of the Amendment

0
Accordingly, under the authority delegated to me by the Administrator,
the FAA amends 14 CFR part 39 as follows:

PART 39--AIRWORTHINESS DIRECTIVES

0
1. The authority citation for part 39 continues to read as follows:

    Authority:  49 U.S.C. 106(g), 40113, 44701.

Sec.  39.13  [Amended]

0
2. The FAA amends Sec.  39.13 by adding the following new AD:

2010-14-11 Bombardier, Inc.: Amendment 39-16356. Docket No. FAA-
2010-0229; Directorate Identifier 2009-NM-115-AD.

Effective Date

    (a) This airworthiness directive (AD) becomes effective August
17, 2010.

Affected ADs

    (b) None.

Applicability

    (c) This AD applies to Bombardier, Inc. Model DHC-8-400, -401,
and -402 airplanes, having serial numbers (S/Ns) 4001, 4003, 4004,
4006, and 4008 through 4227 inclusive, certificated in any category.

    Note 1:  This AD requires revisions to certain operator
maintenance documents to include new inspections. Compliance with
these inspections is required by 14 CFR 91.403(c). For airplanes
that have been previously modified, altered, or repaired in the
areas addressed by these inspections, the operator may not be able
to accomplish the inspections described in the revisions. In this
situation, to comply with 14 CFR 91.403(c), the operator must
request approval for an alternative method of compliance according
to paragraph (j)(1) of this AD. The request should include a
description of changes to the required inspections that will ensure
the continued damage tolerance of the affected structure. The FAA
has provided guidance for this determination in Advisory Circular
(AC) 25.1529-1A.

Subject

    (d) Air Transport Association (ATA) of America Code 32: Landing
gear.

Reason

    (e) The mandatory continuing airworthiness information (MCAI)
states:
    Certain main landing gear components have experienced premature
failure during certification testing. Revision has been made to the
DHC-8-400 Maintenance Requirements Manual, Airworthiness Limitation
Items (ALI), to incorporate the revised safe life limits for the
main landing gear lock actuator assembly, retraction actuator
assembly rod end and piston, and the upper bearing in the main
landing gear shock strut assembly. Failure of these components could
adversely affect the structural integrity of the main landing gear.
    This [Canadian airworthiness] directive is issued to ensure safe
operation of the main landing gear during its service life.

The corrective actions include revising the Airworthiness
Limitations section (ALS) of the Instructions for Continued
Airworthiness, replacing the upper bearing on certain airplanes, and
replacing certain rod ends.

Compliance

    (f) You are responsible for having the actions required by this
AD performed within the compliance times specified, unless the
actions have already been done.

Actions

    (g) For Model DHC-8-400, -401, and -402 airplanes having S/Ns
4001, 4003, 4004, 4006, and 4008 through 4210 inclusive: Do the
actions specified in paragraphs (g)(1) and (g)(2) of this AD.
    (1) Within 60 days after the effective date of this AD: Revise
the ALS of the Instructions for Continued Airworthiness by
incorporating the revised structural safe life limit for the upper
bearing having part number (P/N) 46114-1, as provided in Bombardier
Temporary Revision (TR), ALI-82, dated August 15, 2008, to Part 2,
Airworthiness Limitation Items, of the Bombardier Dash 8 Q400
Maintenance Requirements Manual (MRM), PSM 1-84-7. The initial
compliance time for replacing the upper bearing is specified in
paragraph (g)(2) of this AD.
    (2) Replace the upper bearing having P/N 46114-1 with a new or
serviceable upper bearing, in accordance with Goodrich Dressed Shock
Strut Assembly Main Landing Gear Part No. 46100-29/-31/-33/-35/-37/-
39/-41/-43/-45/-47/-49/-51/-53 and -55 Component Maintenance Manual
with Illustrated Parts List 32-11-03, Revision 11, dated August 22,
2008, at the applicable time specified in paragraphs (g)(2)(i),
(g)(2)(ii), and (g)(2)(iii), of this AD.
    (i) For airplanes having accumulated fewer than 15,000 total
flight cycles as of the effective date of this AD: Replace prior to
the accumulation of 15,000 total flight cycles.
    (ii) For airplanes having accumulated 15,000 total flight cycles
or more, but fewer than 20,000 total flight cycles, as of the
effective date of this AD: Replace prior to the accumulation of
20,000 total flight cycles.
    (iii) For airplanes having accumulated 20,000 total flight
cycles or more as of the effective date of this AD: Replace before
further flight.
    (h) For Model DHC-8-400, -401, and -402 series airplanes having
S/Ns 4001, 4003, 4004, 4006, and 4008 through 4227 inclusive: Do the
applicable actions specified in paragraphs (h)(1) and (h)(2) of this
AD.
    (1) Within 60 days after the effective date of this AD: Revise
the ALS of the Instructions for Continued Airworthiness to
incorporate the revised safe life limits for the retraction actuator
assembly rod end having P/N P3A2750 and P3A2750-1; retraction
actuator assembly piston having P/N 46570-5; lock actuator cylinder
assembly having P/N 46601-1/-3; and lock actuator assembly having P/
N 46600-1/-3/-5/-7; as provided in Bombardier TR ALI-89, dated March
27, 2009, to Part 2, Airworthiness Limitation Items, of the
Bombardier Dash 8 Q400 MRM, PSM 1-84-7. The initial compliance time
for the replacement is specified in the TR, except as provided by
paragraph (h)(2) of this AD.
    (2) For airplanes with a main landing gear retraction actuator
assembly rod end that has accumulated more than 9,850 total flight
cycles as of the effective date of this AD: Within 600 flight cycles
after the effective date of this AD, replace any affected rod end
having P/Ns P3A2750 and P3A2750-1 with a new or serviceable rod end,
in accordance with Goodrich Dressed Shock Strut Assembly Main
Landing Gear Part No. 46100-29/-31/-33/-35/-37/-39/-41/-43/-45/-47/-
49/-51/

-53 and -55 Component Maintenance Manual with Illustrated Parts List
32-11-03, Revision 11, dated August 22, 2008.
    (i) After accomplishing the revision specified in paragraph
(g)(1) or (h)(1) of this AD, except as provided in paragraph (j) of
this AD, no alternative replacement times may be approved for this
part.

    Note 2:  The ALI revisions required by paragraphs (g) and (h) of
this AD may be done by inserting copies of Bombardier TRs ALI-82 and
ALI-89 into Part 2, Airworthiness Limitation Items, of the
Bombardier Dash 8 Q400 MRM, PSM 1-84-7. When these TRs have been
included in the general revision of the MRM, the general revision
may be inserted into the MRM, provided the relevant information in
the general revision is identical to that in Bombardier TRs ALI-82
and ALI-89.

FAA AD Differences

    Note 3:  This AD differs from the MCAI and/or service
information as follows: The MCAI and service information do not
contain replacement procedures for the upper bearings and rod ends.
This AD requires replacing the upper bearings and rod ends in
accordance with Goodrich Dressed Shock Strut Assembly Main Landing
Gear Part No. 46100-29/-31/-33/-35/-37/-39/-41/-43/-45/-47/-49/-51/-
53 and -55 Component Maintenance Manual with Illustrated Parts List
32-11-03, Revision 11, dated August 22, 2008.

Other FAA AD Provisions

    (j) The following provisions also apply to this AD:
    (1) Alternative Methods of Compliance (AMOCs): The Manager, New
York Aircraft Certification Office (ACO), ANE-170, FAA, has the
authority to approve AMOCs for this AD, if requested using the
procedures found in 14 CFR 39.19. Send information to ATTN: Program
Manager, Continuing Operational Safety, FAA, New York ACO, 1600
Stewart Avenue, Suite 410, Westbury, New York, 11590; telephone 516-
228-7300; fax<PHONE_NUMBER>. Before using any approved AMOC on any
airplane to which the AMOC applies, notify your principal
maintenance inspector (PMI) or principal avionics inspector (PAI),
as appropriate, or lacking a principal inspector, your local Flight
Standards District Office. The AMOC approval letter must
specifically reference this AD.
    (2) Airworthy Product: For any requirement in this AD to obtain
corrective actions from a manufacturer or other source, use these
actions if they are FAA-approved. Corrective actions are considered
FAA-approved if they are approved by the State of Design Authority
(or their delegated agent). You are required to assure the product
is airworthy before it is returned to service.
    (3) Reporting Requirements: For any reporting requirement in
this AD, under the provisions of the Paperwork Reduction Act (44
U.S.C. 3501 et seq.), the Office of Management and Budget (OMB) has
approved the information collection requirements and has assigned
OMB Control Number 2120-0056.
    (4) Special Flight Permits: Special flight permits, as described
in Section 21.197 and Section 21.199 of the Federal Aviation
Regulations (14 CFR 21.197 and 21.199), are allowed, provided that
the actions required in paragraph (h) of this AD have been
accomplished.

Related Information

    (k) Refer to MCAI Canadian Airworthiness Directive CF-2009-17,
dated April 22, 2009; Bombardier TR ALI-82, dated August 15, 2008,
and Bombardier TR ALI-89, dated March 27, 2009, to Part 2,
Airworthiness Limitation Items, of the Bombardier Dash 8 Q400
Maintenance Requirements Manual, PSM 1-84-7; and Goodrich Dressed
Shock Strut Assembly Main Landing Gear Part No. 46100-29/-31/-33/-
35/-37/-39/-41/-43/- 45/-47/-49/-51/-53 and -55 Component
Maintenance Manual with Illustrated Parts List 32-11-03, Revision
11, dated August 22, 2008; for related information.

Material Incorporated by Reference

    (l) You must use the service information listed in Table 1 of
this AD, as applicable, to do the actions required by this AD,
unless the AD specifies otherwise.

                                   Table 1--Material Incorporated by Reference
----------------------------------------------------------------------------------------------------------------
           Service information                       Revision                              Date
----------------------------------------------------------------------------------------------------------------
Bombardier Temporary Revision ALI-82 to    Original....................  August 15, 2008.
 Part 2, Airworthiness Limitation Items,
 of the Bombardier Dash 8 Q400
 Maintenance Requirements Manual, PSM 1-
 84-7.
Bombardier Temporary Revision ALI-89 to    Original....................  March 27, 2009.
 Part 2, Airworthiness Limitation Items,
 of the Bombardier Dash 8 Q400
 Maintenance Requirements Manual, PSM 1-
 84-7.
Goodrich Dressed Shock Strut Assembly      11..........................  August 22, 2008.
 Main Landing Gear Part No. 46100-29/-31/-
 33/-35/-37/-39/-41/-43/-45/-47/-49/-51/-
 53 and -55 Component Maintenance Manual
 with Illustrated Parts List 32-11-03.
----------------------------------------------------------------------------------------------------------------

    (The revision level of Goodrich Dressed Shock Strut Assembly
Main Landing Gear Part No. 46100-29/-31/-33/-35/-37/-39/- 41/-43/-
45/-47/-49/-51/-53 and -55 Component Maintenance Manual with
Illustrated Parts List 32-11-03, Revision 11, dated August 22, 2008,
is indicated only on the Record of Revisions; no other page of this
document contains this information. Page LEP-3/4 is missing from the
List of Effective Pages of this document; page LEP 3/4 is dated
August 22, 2008.)
    (1) The Director of the Federal Register approved the
incorporation by reference of this service information under 5
U.S.C. 552(a) and 1 CFR part 51.
    (2) For Bombardier service information identified in this AD,
contact Bombardier, Inc., 400 C[ocirc]te-Vertu Road West, Dorval,
Qu[eacute]bec H4S 1Y9, Canada; telephone<PHONE_NUMBER>; fax 514-855-
7401; e-mail<EMAIL_ADDRESS>Internet http://
www.bombardier.com.
    (3) For Goodrich service information identified in this AD,
contact Goodrich Corporation, Landing Gear, 1400 South Service Road,
West Oakville L6L 5Y7, Ontario, Canada; telephone<PHONE_NUMBER>; e-
mail<EMAIL_ADDRESS>Internet http://www.goodrich.com/
TechPubs.
    (4) You may review copies of the service information at the FAA,
Transport Airplane Directorate, 1601 Lind Avenue, SW., Renton,
Washington. For information on the availability of this material at
the FAA, call<PHONE_NUMBER>.
    (5) You may also review copies of the service information that
is incorporated by reference at the National Archives and Records
Administration (NARA). For information on the availability of this
material at NARA, call<PHONE_NUMBER>, or go to: http://
www.archives.gov/federal_register/code_of_federal_regulations/
ibr_locations.html.

    Issued in Renton, Washington, on June 23, 2010.
Ali Bahrami,
Manager, Transport Airplane Directorate, Aircraft Certification
Service.
[FR Doc. 2010-15923 Filed 7-12-10; 8:45 am]
BILLING CODE 4910-13-P


and (i)(4), on streams with gas content greater than 10 percent
CH4 plus CO2 by weight. Emissions sources in
streams with gas content less than 10 percent CH4 plus
CO2 by weight do not need to be reported. Calculate
emissions from all sources listed in this paragraph using Equation W-19
of this section.
[GRAPHIC] [TIFF OMITTED] TP12AP10.017

    Where:Es,i = Annual total volumetric GHG emissions at
standard conditions from each fugitive source.
    Count = Total number of this type of emission source at the
facility.
    EF = Population emission factor for specific sources listed in
Table W-1 through Table W-7 of this subpart.
    GHGi = for onshore petroleum and natural gas
production facilities and onshore natural gas processing facilities,
concentration of GHG i, CH4 or CO2, in
produced natural gas or feed natural gas; for other facilities
listed in Sec.  98.230 (b)(3) through (b)(8),GHGi equals
1.
    T = Total time the specific source associated with the fugitive
emission was operational in the reporting year, in hours.

    (1) Calculate both CH4 and CO2 mass emissions
from volumetric emissions using calculations in paragraph (v) of this
section.
    (2) Onshore petroleum and natural gas production facilities shall
use the appropriate default population emission factors listed in Table
W-1 of this subpart for fugitive emissions from valves; connectors;
open ended lines; pressure relief valves; compressor starter gas vent;
pump; flanges; other; and CBM well water production. Where facilities
conduct EOR operations the emissions factor listed in Table W-1 shall
be used to estimate all streams of gases, including recycle
CO2 stream. In cases where the stream is almost all
CO2, the emissions factors in Table W-1 shall be assumed to
be for CO2 instead of natural gas.
    (3) Onshore natural gas processing facilities shall use the
appropriate default population emission factor listed in Table W-2 of
this subpart for fugitive emissions from gathering pipelines.
    (4) Underground natural gas storage facilities for storage
wellheads shall use the appropriate default population emission factors
listed in Table W-4 of this subpart for fugitive emissions from
connectors; valves; pressure relief valves; and open ended lines.
    (5) LNG storage facilities shall use the appropriate default
population emission factors listed in Table W-5 of this subpart for
fugitive emissions from vapor recovery compressors.
    (6) LNG import and export facilities shall use the appropriate
default population emission factor listed in Table W-6 of this subpart
for fugitive emissions from vapor recovery compressors.
    (7) Natural gas distribution facilities shall use the appropriate
default population emission factors listed in Table W-7 of this subpart
for fugitive emissions from below grade M&R stations; gathering
pipelines; mains; and services.
    (s) Offshore petroleum and natural gas production facilities in
both state and federal waters. Report GHG emissions from all
``stationary fugitive'' and ``stationary vented'' sources as identified
in the Minerals Management Service (MMS) Gulfwide Offshore Activity
Data System (GOADS) study (2005 Gulfwide Emission Inventory Study MMS
2007-067) for each platform.
    (1) MMS GOADS Reporters. Offshore production facilities currently
reporting under the MMS GOADS program will report the same annual
emissions as calculated by GOADS under paragraph (s) of this section.
    (i) For the first reporting year, report the latest available
emissions from GOADS.
    (ii) In subsequent reporting years when GOADS is updated reporters
shall report the new emissions that are made available from the latest
GOADS software.
    (ii) For each reporting year that does not overlap with the GOADS
reporting year, report the last reported GOADS emissions with emissions
adjusted based on the operating time for each platform.
    (iii) If MMS discontinues or delays their GOADS survey by more than
4 years, then Platform operators shall collect monthly activity data
every 4 years from platform sources in accordance with the latest
version of the MMS GOADS program instructions, beginning in the year
that the GOADS survey would have been conducted, and annual emissions
shall be calculated using the latest available MMS GOADS emission
factors and methods.
    (2) Non-MMS GOADS Reporters. Offshore production facilities not
reporting under the MMS GOADS program shall collect monthly activity
data from platform sources for the first reporting year in accordance
with the latest MMS GOADS program instructions. Annual emissions shall
be calculated using the latest MMS GOADS emission factors and methods.

    (i) In subsequent reporting years, facilities not reporting under
GOADS shall follow the data collection cycle as GOADS in collecting new
activity data monthly to estimate emissions and report emissions.
    (ii) For each reporting year that does not overlap with the GOADS
reporting year, report the last reported emissions data with emissions
adjusted based on the operating time for each platform.
    (iii) If MMS discontinues or delays their GOADS survey by more than
4 years, then Platform operators shall collect monthly activity data
every 4 years from platform sources in accordance with the latest
version of the MMS GOADS program instructions, and annual emissions
shall be calculated using currently available MMS GOADS emission
factors and methods.
    (t) Volumetric emissions. Calculate volumetric emissions at
standard conditions as specified in paragraphs (t)(1) or (2) of this
section.
    (1) Calculate natural gas volumetric emissions at standard
conditions by converting ambient temperature and pressure of natural
gas emissions to standard temperature and pressure natural gas using
Equation W-20 of this section.
[GRAPHIC] [TIFF OMITTED] TP12AP10.018

Where:

Es,n = Natural gas volumetric emissions at standard
temperature and pressure (STP) conditions.
Ea,n = Natural gas volumetric emissions at ambient
conditions.
Ts = Temperature at standard conditions. ([deg]F).
Ta = Temperature at actual emission conditions. ([deg]F).
Ps = Absolute pressure at standard conditions (inches of
Hg).
Pa = Absolute pressure at ambient conditions (inches of
Hg).

    (2) Calculate GHG volumetric emissions at standard conditions by
converting ambient temperature and pressure of GHG emissions to
standard temperature and pressure using Equation W-21 of this section.
[GRAPHIC] [TIFF OMITTED] TP12AP10.019

Where:

    Es,i = GHG i volumetric emissions at standard
temperature and pressure (STP) conditions.
    Ea,i = GHG i volumetric emissions at actual
conditions.
    Ts = Temperature at standard conditions. ([deg]F).
    Ta = Temperature at actual emission conditions.
([deg]F).
    Ps = Absolute pressure at standard conditions (inches
of Hg).
    Pa = Absolute pressure at ambient conditions (inches
of Hg).

    (u) GHG volumetric emissions. Calculate GHG volumetric emissions at
standard conditions as specified in paragraphs (u)(1) and (2) of this
section.
    (1) Estimate CH4 and CO2 emissions from
natural gas emissions using Equation W-22 of this section.
[GRAPHIC] [TIFF OMITTED] TP12AP10.020

Where:

Es,i = GHG i (either CH4 or CO2)
volumetric emissions at standard conditions.
Es,n = Natural gas volumetric emissions at standard
conditions.
Mi = Mole percent of GHG i in the natural gas.

    (2) For Equation W-22 of this section, the mole percent,
Mi, shall be the annual average mole percent for each
facility, as specified in paragraphs (u)(2)(i) through (vii) of this
section.
    (i) GHG mole percent in produced natural gas for onshore petroleum
and natural gas production facilities. If you have a continuous gas
composition analyzer for produced natural gas, you must use these
values in calculating emissions. If you do not have a continuous gas
composition analyzer, then quarterly samples must be taken according to
methods set forth in Sec.  98.234(b).
    (ii) GHG mole percent in feed natural gas for all emissions sources
upstream of the de-methanizer and GHG mole percent in facility specific
residue gas to transmission pipeline systems for all emissions sources
downstream of the de-methanizer overhead for onshore natural gas
processing facilities. If you have a continuous gas composition
analyzer on feed natural gas, you must use these values in calculating
emissions. If you do not have a continuous gas composition analyzer,
then quarterly samples must be taken according to methods set forth in
Sec.  98.234(b).
    (iii) GHG mole percent in transmission pipeline natural gas that
passes through the facility for onshore natural gas transmission
compression facilities.
    (iv) GHG mole percent in natural gas stored in underground natural
gas storage facilities.
    (v) GHG mole percent in natural gas stored in LNG storage
facilities.
    (vi) GHG mole percent in natural gas stored in LNG import and
export facilities.
    (vii) GHG mole percent in local distribution pipeline natural gas
that passes through the facility for natural gas distribution
facilities.
    (v) GHG mass emissions. Calculate GHG mass emissions in carbon
dioxide equivalent at standard conditions by converting the GHG
volumetric emissions into mass emissions using Equation W-23 of this
section.
[GRAPHIC] [TIFF OMITTED] TP12AP10.021

Where:

Masss,i = GHG i (either CH4 or CO2)
mass emissions at standard conditions in metric tons
CO2e.
Es,i = GHG i (either CH4 or CO2)
volumetric emissions at standard conditions, in cubic feet.
[rho]i = Density of GHG i, 0.053 kg/ft\3\ for
CO2 and 0.0193 kg/ft\3\ for CH4.
GWP = Global warming potential, 1 for CO2 and 21 for
CH4.

    (w) EOR injection pump blowdown. Calculate pump blowdown emissions
as follows:
    (1) Calculate the total volume in cubic feet (including, but not
limited to, pipelines, compressors and vessels) between isolation
valves.
    (2) Retain logs of the number of blowdowns per reporting period.
    (3) Calculate the total annual venting emissions using Equation W-
24 of this section:
[GRAPHIC] [TIFF OMITTED] TP12AP10.022

Where:

Massc,i = Annual EOR injection gas venting emissions in
metric tons at critical conditions ``c'' from blowdowns.
N = Number of blowdowns for the equipment in reporting year.
Vv = Total volume in cubic feet of blowdown equipment
chambers (including, but not limited to, pipelines, compressors,
manifolds and vessels) between isolation valves.
Rc = Density of critical phase EOR injection gas in kg/
ft\3\. Use an appropriate standard method published by a consensus-
based standards organization to determine density of super critical
EOR injection gas.
GHGi = Mass fraction of GHGi in critical phase
injection gas.

    (x) Hydrocarbon liquids dissolved CO2. Calculate
dissolved CO2 in hydrocarbon liquids as follows:
    (1) Determine the amount of CO2 retained in hydrocarbon
liquids after flashing in tankage at STP conditions. Quarterly samples
must be taken according to methods set forth in Sec.  98.234(b) to
determine retention of CO2 in hydrocarbon liquids
immediately downstream of the storage tank. Use the average of the
quarterly analysis for the reporting period.
    (2) Estimate emissions using Equation W-25 of this section.
    [GRAPHIC] [TIFF OMITTED] TP12AP10.023

Where:

Masss, CO2 = Annual CO2 emissions from
CO2 retained in hydrocarbon liquids beyond tankage, in
metric tons.
Shl = Amount of CO2 retained in hydrocarbon
liquids in metric tons per barrel, under standard conditions.
Vhl = Total volume of hydrocarbon liquids produced in
barrels in the reporting year.

    (y) Produced water dissolved CO2. Calculate dissolved
CO2 in produced water as follows:
    (1) Determine the amount of CO2 retained in produced
water at STP conditions. Quarterly samples must be taken according to
methods set forth in Sec.  98.234(b) to determine retention of
CO2 in produced water immediately downstream of the
separator where hydrocarbon liquids and produced water are separated.
Use the average of the quarterly analysis for the reporting period.
    (2) Estimate emissions using the Equation W-26 of this section.
    [GRAPHIC] [TIFF OMITTED] TP12AP10.024

Where:

Masss, CO2 = Annual CO2 emissions from
CO2 retained in produced water beyond tankage, in metric
tons.
Spw = Amount of CO2 retained in produced water
in metric tons per barrel, under standard conditions.
Vpw = Total volume of produced water produced in barrels
in the reporting year.

    (3) EOR operations that route produced water from separation
directly to re-injection into the hydrocarbon reservoir in a closed
loop system without any leakage to the atmosphere are exempt from
paragraph (y) of this section.
    (z) Portable equipment combustion emissions. Calculate emissions
from portable equipment using the Tier 1 methodology described in
subpart C of this part (General Stationary Fuel Combustion Sources).

Sec.  98.234  Monitoring and QA/QC requirements.

    (a) You must use the method described as follows to conduct annual
leak detection of fugitive emissions from all source types listed in
Sec.  98.233(p)(3)(i) and (q) in operation or on standby mode that
occur during a reporting period.
    (1) Optical gas imaging instrument. Use an optical gas imaging
instrument for fugitive emissions detection in accordance with 40 CFR
part 60, subpart A, Sec.  60.18(i)(1) and (2) Alternative work practice
for monitoring equipment leaks. In addition, you must operate the
optical gas imaging instrument to image the source types required by
this proposed reporting rule in accordance with the instrument
manufacturer's operating parameters.
    (2) [Reserved]
    (b) All flow meters, composition analyzers and pressure gauges that
are used to provide data for the GHG emissions calculations shall use
measurement methods, maintenance practices, and calibration methods,
prior to the first reporting year and in each subsequent reporting year
using an appropriate standard method published by a consensus standards
organization such as, but not limited to, ASTM International, American
National Standards Institute (ANSI), and American Petroleum Institute
(API). If a consensus based standard is not available, you must use
manufacturer instructions to calibrate the meters, analyzers, and
pressure gauges.
    (c) Use calibrated bags (also known as vent bags) only where the
emissions are at near-atmospheric pressures such that it is safe to
handle and can capture all the emissions, below the maximum temperature
specified by the vent bag manufacturer, and the entire emissions volume
can be encompassed for measurement.
    (1) Hold the bag in place enclosing the emissions source to capture
the entire emissions and record the time required for completely
filling the bag. If the bag inflates in less than one second, assume
one second inflation time.
    (2) Perform three measurements of the time required to fill the
bag, report the emissions as the average of the three readings.
    (3) Estimate natural gas volumetric emissions at standard
conditions using calculations in Sec.  98.233(t).
    (4) Estimate CH4 and CO2 volumetric and mass
emissions from volumetric natural gas emissions using the calculations
in Sec.  98.233(u) and (v).
    (d) Use a high volume sampler to measure emissions within the
capacity of the instrument.
    (1) A technician following manufacturer instructions shall conduct
measurements, including equipment manufacturer operating procedures and
measurement methodologies relevant to using a high volume sampler,
including, but not limited to, positioning the instrument for complete
capture of the fugitive emissions without creating backpressure on the
source.
    (2) If the high volume sampler, along with all attachments
available from the manufacturer, is not able to capture all the
emissions from the source then you shall use anti-static wraps or other
aids to capture all emissions without violating operating requirements
as provided in the instrument manufacturer's manual.
    (3) Estimate CH4 and CO2 volumetric and mass
emissions from volumetric natural gas emissions using the calculations
in Sec.  98.233(u) and (v).
    (4) Calibrate the instrument at 2.5 percent methane with 97.5
percent air and 100 percent CH4 by using calibrated gas
samples and by following manufacturer's instructions for calibration.

Sec.  98.235  Procedures for estimating missing data.

    A complete record of all estimated and/or measured parameters used
in the GHG emissions calculations is required. If data are lost or an
error occurs during annual emissions estimation or measurements, you
must repeat the estimation or measurement activity for those sources as
soon as possible, including in the subsequent reporting year if missing
data are not discovered until after December 31 of the reporting year,
until valid data for reporting is obtained. Data developed and/or
collected in a subsequent reporting year to substitute for missing data
cannot be used for that subsequent year's emissions estimation. Where
missing

data procedures are used for the previous year, at least 30 days must
separate emissions estimation or measurements for the previous year and
emissions estimation or measurements for the current year of data
collection.

Sec.  98.236  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain reported emissions as specified in this
section.
    (a) Report annual emissions separately for each of the industry
segment listed in paragraphs (a) (1) through (8) of this section. For
each segment, report emissions from each source type in the aggregate,
unless specified otherwise. For example, an underground natural gas
storage operation with multiple reciprocating compressors must report
emissions from all reciprocating compressors as an aggregate number.
    (1) Onshore petroleum and natural gas production.
    (2) Offshore petroleum and natural gas production.
    (3) Onshore natural gas processing.
    (4) Onshore natural gas transmission compression.
    (5) Underground natural gas storage.
    (6) LNG storage.
    (7) LNG import and export.
    (8) Natural gas distribution. Report each source in the aggregate
for pipelines and for Metering and Regulating (M&R) stations.
    (b) Report emissions separately for standby equipment.
    (c) Report activity data for each aggregated source type as
follows:
    (1) Count of natural gas pneumatic high bleed devices.
    (2) Count of natural gas pneumatic low bleed devices.
    (3) Count of natural gas driven pneumatic pumps.
    (4) For each acid gas removal unit report the following:
    (i) Total volume of natural gas flow into the acid gas removal
unit.
    (ii) Total volume of natural gas flow out of the acid gas removal
unit.
    (iii) Volume weighted CO2 content of natural gas into
the acid gas removal unit.
    (5) For each dehydrator unit report the following:
    (i) Glycol dehydrators:
    (A) Glycol dehydrator feed natural gas flow rate.
    (B) Glycol dehydrator absorbent circulation pump type.
    (C) Glycol dehydrator absorbent circulation rate.
    (D) Whether stripper gas is used in glycol dehydrator.
    (E) Whether a flash tank separator is used in glycol dehydrator.
    (ii) Desiccant dehydrators:
    (A) The number of desiccant dehydrators operated.
    (B) [Reserved]
    (6) Count of wells vented to the atmosphere for liquids unloading
for each field in the basin.
    (7) Count of wells venting during well completions for each field
in the basin.
    (i) Number of conventional completions.
    (ii) Number of completions involving hydraulic fracturing.
    (8) Count of wells venting during well workovers for each field in
the basin.
    (i) Number of conventional well workovers involving well venting to
the atmosphere.
    (ii) Number of unconventional well workovers involving well venting
to the atmosphere.
    (9) For each compressor blowdown vent stack report the following
for each compressor:
    (i) Type of compressor whether reciprocating or centrifugal.
    (ii) Compressor capacity in horse powers.
    (iii) Volume of gas between isolation valves.
    (iv) Number of blowdowns per year.
    (10) For each estimate of gas emitted from liquids sent to
atmospheric tank using E&P Tank report the following:
    (i) Immediate upstream separator temperature and pressure.
    (ii) Sales oil API gravity.
    (iii) Estimate of individual tank or tank battery capacity in
barrels.
    (iv) Oil, hydrocarbon condensate and water sent to tank(s) in
barrels.
    (v) Control measure: Either vapor recovery system or flaring of
tank vapors.
    (11) For tank emissions identified using optical gas imaging
instrument per Sec.  98.234(a), report the following for each tank:
    (i) Immediate upstream separator temperature and pressure.
    (ii) Sales oil API gravity.
    (iii) Tank capacity in barrels.
    (iv) Tank throughput in barrels.
    (v) Control measure: Either vapor recovery system or flaring of
tank vapors.
    (vi) Optical gas imagining instrument used.
    (vii) Meter used for measuring emissions.
    (viii) List of emissions sources routed to the tank.
    (12) For well testing report the following for each field in the
basin:
    (i) Number of wells tested in reporting period.
    (ii) Average gas to oil ratio for each field.
    (iii) Average flow rate during testing for each field.
    (iv) Average number of days the well is tested.
    (v) Whether the hydrocarbons produced during testing are vented or
flared.
    (13) For associated natural gas venting report the following for
each field in the basin:
    (i) Number of wells venting or flaring associated natural gas in
reporting period.
    (ii) Average gas to oil ratio for each field.
    (iii) Average volume of oil produced per well per field.
    (iv) Whether the associated natural gas is vented or flared.
    (14) For flare stacks report the following for each flare:
    (i) Whether flare has a continuous flow monitor.
    (ii) If using engineering estimation methods, identify sources of
emissions going to the flare.
    (iii) Whether flare has a continuous gas analyzer.
    (iv) Identify proportion of total natural gas to pure hydrocarbon
stream being sent to the flare annually for the reporting period.
    (v) Flare combustion efficiency.
    (15) For well venting for liquids unloading report the following by
field, basin, and well tubing size:
    (i) Number of wells being unloaded for liquids in reporting year.
    (ii) Average number of unloading(s) per well per reporting year.
    (iii) Average volume of natural gas produced per well per reporting
year during liquids unloading.
    (16) For well completions and workovers report the following for
each field in the basin:
    (i) Number of wells completed (worked over) in reporting year.
    (ii) Average number of days required for completion (workover).
    (iii) Average volume of natural gas produced per well per reporting
year during well completion (workover).
    (17) For compressor wet seal degassing vents report the following
for each degassing vent:
    (i) Number of wet seals connected to the degassing vent.
    (ii) Number of compressors whose wet seals are connected to the
degassing vent.
    (iii) Total throughput of compressors whose wet seals are connected
to the degassing vent.
    (iv) Type of meter used for making measurements.
    (v) Whether emissions estimate is based on a continuous or one time
measurement.
    (vi) Total time the compressor(s) associated with the degassing
vent stack

is operating. Sum the hours of operation if multiple compressors are
connected to the vent stack.
    (vii) Proportion of vent gas recovered for fuel gas or sent to a
flare.
    (18) For reciprocating compressor rod packing report the following
per rod packing:
    (i) Total throughput of the reciprocating compressor whose rod
packing emissions is being reported.
    (ii) Total time in hours the reciprocating compressor is in
operating mode.
    (iii) Whether or not the rod packing case is connected to an open
ended line.
    (iv) If rod packing is connected to an open ended line, report type
of device used for measurement emissions.
    (v) If rod packing is not connected to an open ended vent line,
report the locations from where the emissions from the rod packing are
detected.
    (19) For fugitive emissions sources using emission factors for
estimating emissions report the following:
    (i) Component count for each fugitive emissions source.
    (ii) CH4 and CO2 in produced natural gas for
onshore petroleum and natural gas production.
    (20) For EOR injection pump blowdown report the following per pump:
    (i) Pump capacity.
    (ii) Volume of gas between isolation valves.
    (iii) Number of blowdowns per year.
    (iv) Supercritical phase EOR injection gas density.
    (21) For hydrocarbon liquids dissolved CO2 report the
following for each field in the basin:
    (i) Volume of crude oil produced.
    (ii) [Reserved]
    (22) For produced water dissolved CO2 report the
following for each field in the basin:
    (i) Volume of produced water produced.
    (ii) [Reserved]
    (d) Minimum, maximum and average throughput for each operation
listed in paragraphs (a)(1) through (a)(8) of this section.
    (e) For offshore petroleum and natural gas production facilities,
the number of connected wells, and whether the wells are producing oil,
gas, or both.
    (f) Report emissions separately for portable equipment for the
following source types: drilling rigs, dehydrators, compressors,
electrical generators, steam boilers, and heaters.
    (1) Aggregate emissions by source type.
    (2) Report count of each source type.

Sec.  98.237  Records that must be retained.

    In addition to the information required by Sec.  98.3(g), you must
retain the following records:
    (a) Dates on which measurements were conducted.
    (b) Results of all emissions detected and measurements.
    (c) Calibration reports for detection and measurement instruments
used.
    (d) Inputs and outputs of calculations or emissions computer model
runs used for engineering estimation of emissions.

Sec.  98.238  Definitions.

    Except as provided below, all terms used in this subpart have the
same meaning given in the Clean Air Act and subpart A of this part.
    Natural gas distribution facility means the distribution pipelines,
metering stations, and regulating stations that are operated by a Local
Distribution Company (LDC) that is regulated as a separate operating
company by a public utility commission or that are operated as an
independent municipally-owned distribution system.
    Offshore petroleum and natural gas production facility means each
platform structure and all associated equipment as defined in paragraph
(a)(1) of this section. All production equipment that is connected via
causeways or walkways are one facility.
    Onshore petroleum and natural gas production facility means all
petroleum or natural gas equipment associated with all petroleum or
natural gas production wells under common ownership or common control
by an onshore petroleum and natural gas production owner or operator
located in a single hydrocarbon basin as defined by the American
Association of Petroleum Geologists which is assigned a three digit
Geologic Province Code. Where an operating entity holds more than one
permit in a basin, then all onshore petroleum and natural gas
production equipment relating to all permits in their name in the basin
is one onshore petroleum and natural gas production facility.
    Separator means a vessel in which streams of multiple phases are
gravity separated into individual streams of single phase.

 Table W-1 of Subpart W--Default Whole Gas Emission Factors for Onshore
                               Production
------------------------------------------------------------------------
                                                        Emission Factor
                  Onshore production                       (scf/hour/
                                                           component)
------------------------------------------------------------------------
Population Emission Factors--All Components, Gas
 Service
    Valve............................................               0.08
    Connector........................................               0.01
    Open-ended Line..................................               0.04
    Pressure Relief Valve............................               0.17
    Low-Bleed Pneumatic Device Vents.................               2.75
    Gathering Pipelines 1............................               2.81
    CBM Well Water Production 2......................               0.11
Population Emission Factors--All Components, Light
 Crude Service 3
    Valve............................................               0.04
    Connector........................................               0.01
    Open-ended Line..................................               0.04
    Pump.............................................               0.01
    Other 5..........................................               0.24
Population Emission Factors--All Components, Heavy
 Crude Service 4
    Valve............................................              0.001
    Flange...........................................              0.001
    Connector (other)................................             0.0004
    Open-ended Line..................................               0.01
    Other 5..........................................              0.003
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``scf/hour/mile``.
\2\ Emission Factor is in units of ``scf methane/gallon``, in this case
  the operating factor is ``gallons/year'' and do not multiply by
  methane content.

\3\ Hydrocarbon liquids greater than or equal to 20*API are considered
  ``light crude``.
\4\ Hydrocarbon liquids less than 20*API are considered ``heavy crude``.
\5\ ``Others'' category includes instruments, loading arms, pressure
  relief valves, stuffing boxes, compressor seals, dump lever arms, and
  vents.

 Table W-2 of Subpart W--Default Total Hydrocarbon Emission Factors for
                               Processing
------------------------------------------------------------------------
                                       Before  de-         After  de-
                                        methanizer         methanizer
            Processing               emission factor    emission factor
                                        (scf/hour/         (scf/hour/
                                        component)         component)
------------------------------------------------------------------------
Leaker Emission Factors--Reciprocating Compressor Components, Gas
 Service
------------------------------------------------------------------------
Valve.............................              15.88              18.09
Connector.........................               4.31               9.10
Open-ended Line...................              17.90              10.29
Pressure Relief Valve.............               2.01              30.46
Meter.............................               0.02              48.29
------------------------------------------------------------------------
Leaker Emission Factors--Centrifugal Compressor Components, Gas Service
------------------------------------------------------------------------
Valve.............................               0.67               2.51
Connector.........................               2.33               3.14
Open-ended Line...................              17.90              16.17
Dry Seal..........................                105                105
------------------------------------------------------------------------
Leaker Emission Factors--Other Components, Gas Service
------------------------------------------------------------------------
Valve.............................                         6.42
Connector.........................                         5.71
Open-ended Line...................                        11.27
Pressure Relief Valve.............                         2.01
Meter.............................                         2.93
------------------------------------------------------------------------
Population Emission Factors--Other Components, Gas Service
------------------------------------------------------------------------
Gathering Pipelines \1\...........                        2.81
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``scf/hour/mile''.

      Table W-3 of Subpart W--Default Methane Emission Factors for
                              Transmission
------------------------------------------------------------------------
                                                        Emission Factor
                     Transmission                          (scf/hour/
                                                           component)
------------------------------------------------------------------------
Leaker Emission Factors--All Components, Gas Service
------------------------------------------------------------------------
Connector............................................                2.7
Block Valve..........................................               10.4
Control Valve........................................                3.4
Compressor Blowdown Valve............................              543.5
Pressure Relief Valve................................               37.2
Orifice Meter........................................               14.3
Other Meter..........................................                0.1
Regulator............................................                9.8
Open-ended Line......................................               21.5
------------------------------------------------------------------------
Population Emission Factors--Other Components, Gas Service
------------------------------------------------------------------------
Low-Bleed Pneumatic Device Vents.....................               2.57
------------------------------------------------------------------------

Table W-4 of Subpart W--Default Methane Emission Factors for Underground
                                 Storage
------------------------------------------------------------------------
                                                        Emission Factor
                 Underground storage                       (scf/hour/
                                                           component)
------------------------------------------------------------------------
Leaker Emission Factors--Storage Station, Gas Service
------------------------------------------------------------------------
Connector............................................               0.96
Block Valve..........................................               2.02
Control Valve........................................               3.94
Compressor Blowdown Valve............................              66.15
Pressure Relief Valve................................              19.80
Orifice Meter........................................               0.46

Other Meter..........................................               0.01
Regulator............................................               1.03
Open-ended Line......................................               6.01
------------------------------------------------------------------------
Population Emission Factors--Storage Wellheads, Gas Service
------------------------------------------------------------------------
Connector............................................               0.01
Valve................................................               0.10
Pressure Relief Valve................................               0.17
Open-ended Line......................................               0.03
------------------------------------------------------------------------
Population Emission Factors--Other Components, Gas Service
------------------------------------------------------------------------
Low-Bleed Pneumatic Device Vents.....................               2.57
------------------------------------------------------------------------

 Table W-5 of Subpart W--Default Methane Emission Factors for Liquefied
                        Natural Gas (LNG) Storage
------------------------------------------------------------------------
                                                        Emission Factor
                     LNG storage                           (scf/hour/
                                                           component)
------------------------------------------------------------------------
Leaker Emission Factors--LNG Storage Components, LNG Service
------------------------------------------------------------------------
Valve................................................               1.19
Pump Seal............................................               4.00
Connector............................................               0.34
Other\1\.............................................               1.77
------------------------------------------------------------------------
Population Emission Factors--LNG Storage Compressor, Gas Service
------------------------------------------------------------------------
Vapor Recovery Compressor............................              6.81
------------------------------------------------------------------------
\1\ ``other'' equipment type should be applied for any equipment type
  other than connectors, pumps, or valves.

    Table W-6 of Subpart W--Default Methane Emission Factors for LNG
                                Terminals
------------------------------------------------------------------------
                                                        Emission Factor
                    LNG terminals                          (scf/hour/
                                                           component)
------------------------------------------------------------------------
Leaker Emission Factors--LNG Terminals Components, LNG Service
------------------------------------------------------------------------
Valve................................................               1.19
Pump Seal............................................               4.00
Connector............................................               0.34
Other................................................               1.77
------------------------------------------------------------------------
Population Emission Factors--LNG Terminals Compressor, Gas Service
------------------------------------------------------------------------
Vapor Recovery Compressor............................               6.81
------------------------------------------------------------------------

      Table W-7 of Subpart W--Default Methane Emission Factors for
                              Distribution
------------------------------------------------------------------------
                                                        Emission Factor
                     Distribution                          (scf/hour/
                                                           component)
------------------------------------------------------------------------
Leaker Emission Factors--Above Grade M&R Stations Components, Gas
 Service
------------------------------------------------------------------------
Connector............................................               1.69
Block Valve..........................................              0.557
Control Valve........................................               9.34
Pressure Relief Valve................................              0.270
Orifice Meter........................................              0.212
Regulator............................................              0.772
Open-ended Line......................................             26.131
------------------------------------------------------------------------
Population Emission Factors--Below Grade M&R Stations Components, Gas
 Service \1\
------------------------------------------------------------------------
Below Grade M&R Station, Inlet Pressure > 300 psig...               1.30

Below Grade M&R Station, Inlet Pressure 100 to 300                  0.20
 psig................................................
Below Grade M&R Station, Inlet Pressure < 100 psig...               0.10
------------------------------------------------------------------------
Population Emission Factors--Distribution Mains, Gas Service \2\
------------------------------------------------------------------------
Unprotected Steel....................................              12.58
Protected Steel......................................               0.35
Plastic..............................................               1.13
Cast Iron............................................              27.25
------------------------------------------------------------------------
Population Emission Factors--Distribution Services, Gas Service \2\
------------------------------------------------------------------------
Unprotected Steel....................................               0.19
Protected Steel......................................               0.02
Plastic..............................................              0.001
Copper...............................................              0.03
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``scf/hour/station``
\2\ Emission Factor is in units of ``scf/hour/service``

 Table W-8 of Subpart W--Default Nitrous Oxide Emission Factors for Gas
                                 Flaring
------------------------------------------------------------------------
                                                        Emission Factor
                                                         (metric tons/
                     Gas Flaring                           MMscf gas
                                                         production or
                                                           receipts)
------------------------------------------------------------------------
Population Emission Factors--Gas Flaring
------------------------------------------------------------------------
Gas Production.......................................           5.90E-07
Sweet Gas Processing.................................           7.10E-07
Sour Gas Processing..................................           1.50E-06
Conventional Oil Production \1\......................           1.00E-04
Heavy Oil Production \2\.............................          7.30E-05
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``metric tons/barrel conventional oil
  production``
\2\ Emission Factor is in units of ``metric tons/barrel heavy oil
  production``

[FR Doc. 2010-6767 Filed 4-9-10; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register Volume 84, Number 139 (Friday, July 19, 2019)]
[Notices]
[Pages 34918-34919]
[FR Doc No: 2019-15432]

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DEPARTMENT OF HOMELAND SECURITY

Federal Emergency Management Agency

[Docket ID: FEMA-2019-0004; OMB No. 1660-0011]

Agency Information Collection Activities: Proposed Collection;
Comment Request; Submission for OMB Review; Comment Request; Debt
Collection Financial Statement

AGENCY: Federal Emergency Management Agency, DHS.

ACTION: Notice and request for comments.

-----------------------------------------------------------------------

SUMMARY: The Federal Emergency Management Agency, as part of its
continuing effort to reduce paperwork and respondent burden, invites
the general public to take this opportunity to comment on a
reinstatement, without change, of a previously approved information
collection for which approval has expired. In accordance with the
Paperwork Reduction Act of 1995, this notice seeks comments on the
collection of information related to disaster program accounts and
debts owed to FEMA by individuals.

DATES: Comments must be submitted on or before September 17, 2019.

ADDRESSES: To avoid duplicate submissions to the docket, please use
only one of the following means to submit comments:
    (1) Online. Submit comments at www.regulations.gov under Docket ID
FEMA-2019-0004. Follow the instructions for submitting comments.
    (2) Mail. Submit written comments to Docket Manager, Office of
Chief Counsel, DHS/FEMA, 500 C Street SW, 8NE, Washington, DC 20472-
3100.
    All submissions received must include the agency name and Docket
ID. Regardless of the method used for submitting comments or material,
all submissions will be posted, without change, to the Federal
eRulemaking Portal at http://www.regulations.gov, and will include any
personal information you provide. Therefore, submitting this
information makes it public. You may wish to read the Privacy Act
notice that is available via the link in the footer of
www.regulations.gov.

FOR FURTHER INFORMATION CONTACT: You may contact the Information
Management Division for copies of the proposed collection of
information at email address<EMAIL_ADDRESS>or Zita Zduoba, FEMA Finance Center, Office of
the Chief Financial Officer, at<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION: Under the Debt Collection Act as amended (31
U.S.C. 3701, et. seq.), the Federal Claims Collection Standards (31 CFR
parts 900-904), and the Department of Homeland Security (DHS)
regulations (6 CFR Part 11); the Administrator of the Federal Emergency
Management Agency (FEMA) is: (1) Required to attempt collection of all
debts owed to the United States arising out of activities of the FEMA;
and (2) for debts not exceeding $100,000, authorized to compromise such
debts or terminate collection action completely where it appears that
no person is liable for such debt or has the present or prospective
financial ability to pay a significant sum or that the cost of
collecting such debt is likely to exceed the amount of the recovery (31
U.S.C. 3711(a)(2)).
    This information collection expired on June 30, 2019. FEMA is
requesting a reinstatement, without change, of a previously approved
information collection for which approval has expired.

Collection of Information

    Title: Debt Collection Financial Statement.
    Type of information collection: Reinstatement, without change, of a
previously approved information collection for which approval has
expired.
    OMB Number: 1660-0011.
    Form Titles and Numbers: Debt Collection Financial Statement, FEMA
form 127-0-1.
    Abstract: FEMA Form 127-0-1 is used to collect information provided
voluntarily by the debtor to evaluate the debtor's financial abilities
to determine if they qualify for a payment plan and set repayment terms
or determine a compromise to write-off a debt in part or in full.
Financial information obtained is essential to evaluate the debtor's
ability for the payment of the debt in part or in full. Debt may be a
recoupment of an ineligible disaster assistance payment or improper
payment to an employee.
    Affected Public: Individuals or households.
    Estimated Number of Respondents: 300.
    Estimated Number of Responses: 300.
    Estimated Total Annual Burden Hours: 225.

    Estimated Total Annual Respondent Cost: $8,206.
    Estimated Respondents' Operation and Maintenance Costs: $0.
    Estimated Respondents' Capital and Start-Up Costs: $0.
    Estimated Total Annual Cost to the Federal Government: $41,661.

Comments

    Comments may be submitted as indicated in the ADDRESSES caption
above. Comments are solicited to (a) evaluate whether the proposed data
collection is necessary for the proper performance of the agency,
including whether the information shall have practical utility; (b)
evaluate the accuracy of the agency's estimate of the burden of the
proposed collection of information, including the validity of the
methodology and assumptions used; (c) enhance the quality, utility, and
clarity of the information to be collected; and (d) minimize the burden
of the collection of information on those who are to respond, including
through the use of appropriate automated, electronic, mechanical, or
other technological collection techniques or other forms of information
technology, e.g., permitting electronic submission of responses.

Maile Arthur,
Acting Records Management Branch Chief, Office of the Chief
Administrative Officer, Mission Support, Federal Emergency Management
Agency, Department of Homeland Security.
[FR Doc. 2019-15432 Filed 7-18-19; 8:45 am]
BILLING CODE 9111-19-P


[Federal Register Volume 87, Number 46 (Wednesday, March 9, 2022)]
[Notices]
[Page 13288]
[FR Doc No: 2022-04952]

-----------------------------------------------------------------------

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings

    Take notice that the Commission has received the following Natural
Gas Pipeline Rate and Refund Report filings:

Filings Instituting Proceedings

    Docket Numbers: RP22-672-000.
    Applicants: Bear Creek Storage Company, L.L.C.
    Description: Compliance filing: Annual Report on Operational
Transactions 2022 to be effective N/A.
    Filed Date: 3/2/22.
    Accession Number: 20220302-5035.
    Comment Date: 5 p.m. ET 3/14/22.

    Docket Numbers: RP22-673-000.
    Applicants: Rover Pipeline LLC.
    Description: Sec.  4(d) Rate Filing: Summary of Negotiated Rate
Capacity Release Agreements on 3-2-22 to be effective 3/1/2022.
    Filed Date: 3/2/22.
    Accession Number: 20220302-5052.
    Comment Date: 5 p.m. ET 3/14/22.

    Docket Numbers: RP22-674-000.
    Applicants: Texas Eastern Transmission, LP.
    Description: Sec.  4(d) Rate Filing: Quality of Gas--PTR Language
Modification eff 4-1-22 to be effective 4/1/2022.
    Filed Date: 3/2/22.
    Accession Number: 20220302-5213.
    Comment Date: 5 p.m. ET 3/14/22.

    Any person desiring to intervene or protest in any of the above
proceedings must file in accordance with Rules 211 and 214 of the
Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00
p.m. Eastern time on the specified comment date. Protests may be
considered, but intervention is necessary to become a party to the
proceeding.
    The filings are accessible in the Commission's eLibrary system
(https://elibrary.ferc.gov/idmws/search/fercgensearch.asp) by querying
the docket number.
    eFiling is encouraged. More detailed information relating to filing
requirements, interventions, protests, service, and qualifying
facilities filings can be found at: http://www.ferc.gov/docs-filing/efiling/filing-req.pdf. For other information, call<PHONE_NUMBER>
(toll free). For TTY, call<PHONE_NUMBER>.

    Dated: March 3, 2022.
Debbie-Anne A. Reese,
Deputy Secretary.
[FR Doc. 2022-04952 Filed 3-8-22; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 82, Number 114 (Thursday, June 15, 2017)]
[Rules and Regulations]
[Pages 27423-27424]
[FR Doc No: 2017-12417]

=======================================================================
-----------------------------------------------------------------------

DEPARTMENT OF HOMELAND SECURITY

Coast Guard

33 CFR Part 117

[Docket No. USCG-2017-0510]

Drawbridge Operation Regulation; Sacramento River, Rio Vista, CA

AGENCY: Coast Guard, DHS.

ACTION: Notice of deviation from drawbridge regulation.

-----------------------------------------------------------------------

SUMMARY: The Coast Guard has issued a temporary deviation from the
operating schedule that governs the Rio Vista Drawbridge across the
Sacramento River, mile 12.8, at Rio Vista, CA. The deviation is
necessary to allow the bridge owner to make necessary emergency repairs
to the bridge. This deviation allows the bridge to open with one hour
advance notice during the deviation period.

DATES: This deviation is effective from 7 p.m. on June 16, 2017 to 4
a.m. on July 1, 2017.

ADDRESSES: The docket for this deviation [USCG-2017-0510], is available
at http://www.regulations.gov. Type the docket number in the ``SEARCH''
box and click ``SEARCH.'' Click on Open Docket Folder on the line
associated with this deviation.

FOR FURTHER INFORMATION CONTACT: If you have questions on this
temporary deviation, call or email Carl T. Hausner, Chief, Bridge
Section, Eleventh Coast Guard District; telephone<PHONE_NUMBER>; email
<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION: The California Department of Transportation
has requested a temporary change to the operation of the Rio Vista
Drawbridge, mile 12.8, over Sacramento River, at Rio Vista, CA. The
drawbridge navigation span provides a vertical clearance of 18 feet
above Mean High Water in the closed-to-navigation position. In
accordance with 33 CFR 117.5, the draw opens on signal. Navigation on
the waterway is commercial, search and rescue, law enforcement, and
recreational.
    The drawspan will require a one hour advance notice at three
specified periods: (1) From 7 p.m. on June 16, 2017 to 4 a.m. on June
17, 2017; (2) from 8 p.m. on June 24, 2017 to 7 a.m. on June 25, 2017;
and (3) from 7 p.m. on June 30, 2017 to 4 a.m. on July 1, 2017, to
allow the bridge owner to make emergency repairs to the bridge deck. A
one hour advance notice will give enough time for the contractor to
clear away equipment and workers before the drawspan can safely open
for transiting vessels. Scaffolding will be installed below the bridge
deck from June 16, 2017 through July 1, 2017, reducing the vertical
clearance by 4 feet, and will extend from the west tower 48 feet into
the navigational channel. This temporary deviation has been coordinated
with the waterway users.

No objections to the proposed temporary deviation were raised.
    Vessels able to pass through the bridge in the closed position may
do so at anytime. The bridge will be able to open for emergencies with
one hour advance notice. There is no immediate alternate route for
vessels to pass. The Coast Guard will also inform the users of the
waterway through our Local and Broadcast Notices to Mariners of the
change in operating schedule for the bridge so vessel operators can
arrange their transits to minimize any impact caused by the temporary
deviation.
    In accordance with 33 CFR 117.35(e), the drawbridge must return to
its regular operating schedule immediately at the end of the effective
period of this temporary deviation. This deviation from the operating
regulations is authorized under 33 CFR 117.35.

    Dated: June 12, 2017.
C.T. Hausner,
District Bridge Chief, Eleventh Coast Guard District.
[FR Doc. 2017-12417 Filed 6-14-17; 8:45 am]
 BILLING CODE 9110-04-P