[Federal Register Volume 74, Number 139 (Wednesday, July 22, 2009)]
[Proposed Rules]
[Pages 36139-36151]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: E9-17307]
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DEPARTMENT OF TRANSPORTATION
Pipeline and Hazardous Materials Safety Administration
49 CFR Parts 192, 193, and 195
[Docket No. PHMSA-2008-0301)
RIN 2137-AE41
Pipeline Safety: Periodic Updates of Regulatory References to
Technical Standards and Miscellaneous Edits
AGENCY: Pipeline and Hazardous Materials Safety Administration (PHMSA),
Department of Transportation (DOT).
ACTION: Notice of proposed rulemaking (NPRM).
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SUMMARY: PHMSA is proposing to incorporate by reference (IBR) into the
pipeline safety regulations all or parts of new editions of voluntary
consensus standards to allow pipeline operators to use current
technology, new materials, and other industry and management practices.
In this document, PHMSA also proposes to make nonsubstantive edits and
clarify regulatory language in certain provisions. These proposed
amendments to the pipeline safety regulations would not require
pipeline operators to undertake any significant new pipeline safety
initiatives.
DATES: Submit comments on the subject of this proposed rule on or
before September 21, 2009.
ADDRESSES: You may submit comments, identified by Docket No. PHMSA-
2008-0301, by any of the following methods:
E-Gov Web: http://www.regulations.gov. This site allows
the public to enter comments on any Federal Register notice issued by
any agency. Follow the online instructions for submitting comments.
Mail: Docket Management System: U.S. Department of
Transportation, 1200 New Jersey Avenue, SE., West Building Ground
Floor, Room W12-140, Washington, DC 20590-0001.
Hand Delivery or Courier: DOT Docket Management System:
West Building Ground Floor, Room W12-140, 1200 New Jersey Avenue, SE.,
between 9 a.m. and 5 p.m. ET, Monday through Friday, except Federal
holidays.
Fax: 202-493-2251.
Instructions: Identify the docket ID, PHMSA 2008-0301, at the
beginning of your comments. If you submit your comments by mail, submit
two copies. If you wish to receive confirmation that PHMSA received
your comments, include a self-addressed stamped postcard. Internet
users may submit comments at http://www.regulations.gov.
Note: All comments received will be posted without edits to
http://www.regulations.gov, including any personal information
provided. Please see the Privacy Act heading below.
Privacy Act: Anyone is able to search the electronic comments
received into any of our dockets by the name of the individual
submitting the comment (or signing the comment, if submitted on behalf
of an association, business, labor union). You may review DOT's
complete Privacy Act Statement in the Federal Register published on
April 11, 2000 (65 FR 19477-78) or you may visit http://docketsinfo.dot.gov/.
Docket: For access to the docket to read background documents or
comments received, go to http://www.regulations.gov. Follow the online
instructions for accessing the dockets. Alternatively, you may review
the documents in person at the street address listed above.
FOR FURTHER INFORMATION CONTACT:
Technical Information: Mike Israni, (202) 366-4571, or by e-mail at
[email protected].
Regulatory Information: Cheryl Whetsel by phone at (202) 366-4431
or by e-mail at [email protected].
SUPPLEMENTARY INFORMATION:
I. Background
The National Technology Transfer and Advancement Act of 1995 (Pub.
L. 104-113; signed into law March 7, 1996)
[[Page 36140]]
directs Federal agencies to use voluntary consensus standards instead
of government-written standards. The Office of Management and Budget
(OMB) Circular A-119: Federal Participation in the Development and Use
of Voluntary Consensus Standards and in Conformity Assessment
Activities sets the policies on Federal use and development of
voluntary consensus standards. Voluntary consensus standards are
standards developed or adopted by voluntary bodies that develop,
establish, or coordinate technical standards using agreed upon
procedures. These organizations update and revise their published
standards every 3 to 5 years, to reflect modern technology and best
technical practices.
PHMSA's Office of Pipeline Safety staff participates in more than
25 national voluntary consensus standards committees. There are more
than 60 standards and specifications incorporated by reference in 49
CFR parts 192, 193, and 195. PHMSA's policy is to adopt voluntary
consensus standards when they are applicable to pipeline design,
construction, maintenance, inspection, and repair. PHMSA has the
ultimate responsibility to ensure that the best interests of public
safety are being served. When PHMSA believes some aspect of a standard
does not meet this directive, it will not incorporate the new edition.
PHMSA has reviewed the revised voluntary consensus standards proposed
for incorporation in whole or in part in 49 CFR parts 192, 193, and
195.
Previous updates to incorporate industry standards by reference
were published May 24, 1996 (61 FR 26121), June 6, 1996 (61 FR 2877),
February 17, 1998 (63 FR 7721), June 14, 2004 (69 FR 32886), June 9,
2006 (71 FR 33402), and February 1, 2007 (72 FR 4657).
II. Updated Standards Not Incorporated by Reference
PHMSA will not propose to incorporate by reference the following
updated ASTM International (ASTM), formerly known as the American
Society of Testing and Materials, standards.
--ASTM D638; Standard Test Method for Tensile Properties of Plastics
(2008 edition)
--ASTM D2513; Standard Specification for Thermoplastic Gas Pressure
Pipe, Tubing and Fittings (2007 edition)
--ASTM D2517; Standard Specification for Reinforced Epoxy Resin Gas
Pressure Pipe and Fittings (2006)
--ASTM F1055; Standard Specification for Electrofusion-Type
Polyethylene Fittings for Outside Diameter Controller Polyethylene Pipe
and Tubing (2006)
PHMSA believes that a number of important issues need to be fully
addressed by ASTM Committee F-17 and D20.10 before we adopt any new
editions. Among these are the issues of appurtenances, marking and or
traceability, increase in design factor, and qualifications
requirements for new materials. Therefore, we are proposing to continue
to reference in the gas pipeline safety regulations the standards found
in ASTM D638 (2003 edition), (ASTM D2513 1987 and 1999 edition), ASTM
D2517 (2000 edition) and ASTM F1055 (1998 edition) for plastic pipe and
fittings.
PHMSA has determined that the following updated National Fire
Protection Association (NFPA) standards will not be incorporated by
reference at this time.
--NFPA 58; Liquefied Petroleum Gas Code (LP-Gas Code) (2008 edition)
--NFPA 59; Utility LP-Gas Plant Code (2008 edition)
PHMSA currently requires that the NFPA standards prevail if there
is a conflict between Part 192 and NFPA Standards 58 or 59. PHMSA is
proposing a change to paragraph (c) in Sec. 192.11 for petroleum gas
systems. This requirement was put in place to take advantage of more
current petroleum gas transportation technology and safety practices.
However, PHMSA has noticed that Sec. 192.11(c) is consistently being
misinterpreted by operators. Also, we believe the 2008 editions of NFPA
Standards 58 and 59 have many conflicts with Part 192. Therefore, we
are proposing to revise the regulation to require that Part 192 will
prevail if there is a conflict between Part 192 and NFPA 58 or NFPA 59.
PHMSA believes the updated NFPA 58 would supplant the requirements
of Part 192 with lesser criteria in the areas of damage prevention;
odorization requirements; distribution valve maintenance; and operation
and maintenance, emergency, and public awareness planning. In addition,
because NFPA 58 does not apply retroactively, the 2008 revisions would
not apply to those regulated facilities in existence before this
edition was issued. This would create a situation where significant
portions of Part 192 would apply to some facilities and NFPA 58 (2008)
would apply to others. PHMSA also believes the 2008 edition of NFPA 59
is not in concert with the scope of pipeline facilities as designated
in Part 192.1(b)(5), and with Subpart I--Requirements for Corrosion
Control. Therefore, we are proposing to continue to reference in the
pipeline safety regulations the standards found in NFPA 58 (2004) and
NFPA 59 (2004).
III. Updated Standards Partially Incorporated by Reference
PHMSA is proposing to partially incorporate NFPA 59A, Standard for
the Production, Storage, and Handling of Liquefied Natural Gas (LNG)
(2006 edition) at this time. We are proposing to reference in Part 193
only those specified sections of the 2006 edition pertaining to
ultrasonic inspection and to seismic design. PHMSA believes that the
NFPA 59A committee has yet to reconcile issues relating to dispersion
analyses for vapor releases from process and safety equipment;
containers with liquid penetrations at grade; design spill cases for
full and double containment containers; standards for impoundment
sizing for snow accumulation, severe weather, emergency
depressurization, and fuel bunkering. Therefore, except for specified
sections in the 2006 edition, PHMSA proposes to continue to reference
NFPA 59A (2001).
IV. Updates to Standards Incorporated by Reference
PHMSA proposes the following new editions of currently-referenced
standards for incorporation by reference (IBR) in parts 192, 193, and
195. PHMSA is also proposing to amend the titles in the applicable
referenced sections to reflect the updated standards as appropriate.
This notice proposes to incorporate all or parts of the latest editions
of 39 voluntary consensus technical standards referenced in the
pipeline safety regulations.
API RP 5L1 & API RP 5LW
PHMSA proposes to adopt American Petroleum Institute (API)
Recommended Practice 5LW (API RP 5LW) ``Transportation of Line Pipe on
Barges and Marine Vessels'' into 49 CFR parts 192 and 49 CFR 195. This
newly-incorporated standard would be referenced in Sec. 192.65 and a
newly-created Sec. 195.207. API RP 5LW would provide a standard for
transportation of certain API Specification 5L steel line pipe by ship
or barge on both inland and marine waterways. PHMSA also proposes to
incorporate by reference API RP 5L1 into the newly-created Sec.
195.207 similar to how it is incorporated by reference in Sec. 192.65.
This would provide a standard for liquid operators for the
transportation of certain API Specification 5L steel line pipe by
railroad.
[[Page 36141]]
API 620
PHMSA proposes to adopt API 620 (2008) ``Design and Construction of
Large, Welded, Low-Pressure Storage Tanks'' in 49 CFR Part 193 for
seismic design and nondestructive examination. NFPA 59A (2006)
incorporates by reference the 1990 edition of API 620 but PHMSA
proposes to incorporate by reference the most recent version, API 620
(2008).
American Petroleum Institute (API)
ANSI/API Spec 5L/ISO 3183 Specification for Line Pipe
(44th edition, 2007), Includes Errata and Addendum (2009)
Replaces IBR: API Specification 5L, ``Specification for Line Pipe''
(43rd edition and errata, 2004);
Referenced in 49 CFR 192.55(e); 192.113; Item I, Appendix B to part
192; 195.106(b)(1)(i); 195.106(e).
API Spec 5LW API Recommended Practice 5LW, ``Recommended
Practice for `Transportation of Line Pipe on Barges and Marine Vessels'
'' (2nd edition, 1996)
Proposed to be IBR;
Proposed to be Referenced in 49 CFR 192.65(b); 195.207(b).
API Spec 6D/ISO 14313 ``Pipeline Valves'' (23rd edition
and errata 1, 2 and 3, (2009)
Replaces IBR: API Specification 6D ``Pipeline Valves'' (22nd
edition, January 2002);
Referenced in 49 CFR 192.145(a); 195.116(d).
ANSI/API 12F, Specification for Shop Welded Tanks for
Storage of Production Liquids (11th edition errata, February 2007)
Replaces IBR: 11th edition, 1994;
Referenced in 49 CFR 195.132(b)(1); 195.205(b)(2); 195.264(b)(1);
195.264(e)(1); 195.307(a); 195.565; 195.579(d).
ANSI/API 510, ``Pressure Vessel Inspection Code:
Maintenance Inspection, Rating, Repair, and Alteration,'' (9th edition,
June 2006)
Replaces IBR: 8th edition, 1997 including Addenda 1 through 4;
Referenced in 49 CFR 195.205(b)(3); 195.432(c).
API 620, ``Design and Construction of Large, Welded, Low-
Pressure Storage Tanks'' (11th edition, February 2008, Addendum 1,
2009)
Replaces IBR: 10th edition, 2002 including Addendum 1;
Referenced in 49 CFR 195.132(b)(2); 195.205(b)(2);
195.264(b)(1);195.264(e)(3); 195.307(b)
Reference added in 49 CFR 193.2101(b), 193.2321(b).
API 650, ``Welded Steel Tanks for Oil Storage,'' (11th
edition, June 2007, Addendum 1, 2008)
Replaces IBR: 10th edition, 1998 including Addenda 1-3;
Referenced in 49 CFR 195.132(b)(3); 195.205(b)(1); 195.264(b)(1);
195.264(e)(2); 195.307; 195.565; 195.579(d).
ANSI/API Recommended Practice 651, ``Cathodic Protection
of Aboveground Petroleum Storage Tanks'' (3rd edition, January 2007)
Replaces IBR: 2nd edition, December 1997;
Referenced in 49 CFR 195.565; 195.579(d).
ANSI/API Recommended Practice 652, ``Lining of Aboveground
Petroleum Storage Tank Bottoms,'' (3rd edition, October 2005)
Replaces IBR: 2nd edition, December 1997;
Referenced in 49 CFR 195.579(d).
API 653, ``Tank Inspection, Repair, Alteration, and
Reconstruction,'' (3rd edition, includes Addendum 1 (2003), Addendum 2
(2005), Addendum 3 (2008), and Errata (2008), April 2008)
Replaces IBR: 3rd edition, 2001 including Addendum 1, 2003;
Referenced in 49 CFR 195.205(b)(1); 195.432(b).
API 1104, ``Welding of Pipelines and Related Facilities,''
(20th edition, Errata/Addendum, (2007) and Errata 2 (2008))
Replaces IBR: 19th edition, 1999, including Errata October 31,
2001;
Referenced in 49 CFR 192.225; 192.227(a); 192.229(c)(1);
192.241(c); Item II, Appendix B; 195.222; 195.228(b); 195.214(a).
API 1130, ``Computational Pipeline Monitoring for Liquid
Pipelines'' (1st edition, September 2007)
Replaces IBR: 2nd edition, 2002;
Referenced in 49 CFR 195.134; 195.444.
API 2000, ``Venting Atmospheric and Low-Pressure Storage
Tanks'' (5th edition, errata, November 1999)
Replaces IBR: 5th edition, April 1998;
Referenced in 49 CFR 195.264(e)(2); 195.264(e)(3).
API Recommended Practice 2003, ``Protection against
Ignitions Arising Out of Static, Lightning, and Stray Currents,'' (7th
edition, January 2008)
Replaces IBR: 6th edition, 1998;
Referenced in 49 CFR 195.405(a).
API 2026, ``Safe Access/Egress Involving Floating Roofs of
Storage Tanks in Petroleum Service,'' (2nd edition, reaffirm, June
2006)
Replaces IBR: 2nd edition, 1998;
Referenced in 49 CFR 195.405(b).
API Recommended Practice 2350 ``Overfill Protection for
Storage Tanks in Petroleum Facilities,'' (3rd edition, January 2005)
Replaces IBR: 2nd edition, 1996;
Referenced in 49 CFR 195.428(c).
American Society of Civil Engineers (ASCE)
ASCE/SEI 7-05, ``Minimum Design Loads for Buildings and
Other Structures'' (2005 edition)
Replaces IBR: 2002 edition;
Referenced in 49 CFR 193.2067.
American Society for Testing and Materials (ASTM)
ASTM A53/A53M-07 (2007), ``Standard Specification for
Pipe, Steel, Black and Hot-Dipped, Zinc-Coated, Welded and Seamless''
Replaces IBR: 2004 edition;
Referenced in 49 CFR 192.113; Item I, Appendix B to part 192;
195.106(e).
ASTM A106/106M-08 (2008), ``Standard Specification for
Seamless Carbon Steel Pipe for High-Temperature Service''
Replaces IBR: 2004 edition;
Referenced in 49 CFR 192.113; Item I, Appendix B to part 192;
195.106(e).
ASTM A372/A372M-03 (2008), ``Standard Specification for
Carbon and Alloy Steel Forgings for Thin-Walled Pressure Vessels''
Replaces IBR: 2003 edition;
Referenced in 49 CFR 192.177(b)(1).
ASTM A381-96 (Reapproved 2005), ``Standard Specification
for Metal-Arc-Welded Steel Pipe for Use with High-Pressure Transmission
Systems''
Replaces IBR: 1996 edition, reapproved 2001;
Referenced in 49 CFR 192.113; Item I, Appendix B to part 192;
195.106(e).
ASTM A671-06 (2006), ``Standard Specification for
Electric-Fusion-Welded Steel Pipe for Atmospheric and Lower
Temperatures''
Replaces IBR: 2004 edition;
Referenced in 49 CFR 192.113; Item I, Appendix B to part 192;
195.106(e).
ASTM A672-08 (2008), ``Standard Specification for
Electric-Fusion-Welded Steel Pipe for High-Pressure Service at Moderate
Temperatures''
Replaces IBR: 1996 edition, reapproved 2001;
Referenced in 49 CFR 192.113; Item I, Appendix B to part 192;
195.106(e).
ASTM A691-98 (2007), ``Standard Specification for Carbon
and Alloy Steel Pipe, Electric-Fusion-Welded for High-Pressure Service
at High Temperatures''
Replaces IBR: 1998 edition, reapproved 2002;
Referenced in 49 CFR 192.113; Item I, Appendix B to part 192;
195.106(e).
ASME International (ASME)
ANSI/ASME B16.1-2005, Gray Iron Pipe Flanges and Flanged
Fittings: Classes 25, 125, and 250 (August 2006)
Replaces IBR: ASME B16.1-1998 ``Cast Iron Pipe Flanges and Flanged
Fittings'' 1998 edition;
[[Page 36142]]
Referenced in 49 CFR 192.147(c).
ANSI/ASME B16.9-2007, ``Factory-Made Wrought Steel Butt
Welding Fittings'' (December 2007)
Replaces IBR: 2003 edition (February 2004);
Referenced in 49 CFR 195.118(a).
ANSI/ASME B31.4-2006 ``Pipeline Transportation Systems for
Liquid Hydrocarbons and Other Liquids'' (October 2006)
Replaces IBR: 2002 edition (October 2002);
Referenced in 49 CFR 195.452(h)(4)(i).
ANSI/ASME B31.8-2007 ``Gas Transmission and Distribution
Piping Systems'' (November 2007)
Replaces IBR: 2003 edition (February 2004);
Referenced in 49 CFR 192.619(a)(1)(i); 195.5(a)(1)(i);
195.406(a)(1)(i).
ASME Boiler and Pressure Vessel Code, Section I: Rules for
Construction of Power Boilers 2007 (July 2007)
Replaces IBR: 2004 edition, including addenda through July 1, 2005;
Referenced in 49 CFR 192.153(a).
ASME Boiler and Pressure Vessel Code, Section VIII,
Division 1: Rules for Construction of Pressure Vessels 2007 (July 2007)
Replaces IBR: 2004 edition, including addenda through July 1, 2005;
Referenced in 49 CFR 192.153(b); 192.165(b)(3); 193.2321;
195.307(e).
ASME Boiler and Pressure Vessel Code, Section VIII,
Division 2: Alternative Rules 2007 (July 2007)
Replaces IBR: 2004 edition, including addenda through July 1, 2005;
Referenced in 49 CFR 192.153(b); 192.165(b)(3); 193.2321;
195.307(e).
ASME Boiler and Pressure Vessel Code, Section IX: Welding
and Brazing Qualifications 2007 (July 2007)
Replaces IBR: 2004 edition, including addenda through July 1, 2005;
Referenced in 49 CFR 192.227(a); Item II, Appendix B to part 192;
195.222.
Gas Technology Institute (GTI)
GTI-04/0032 LNGFIRE3: A Thermal Radiation Model for LNG
Fires (2004)
Replaces IBR: GRI-89/0176 ``LNGFIRE: A Thermal Radiation Model for
LNG Fires'' (June 29, 1990);
Referenced in 49 CFR 193.2057.
Manufacturers Standardization Society of the Valve and Fittings
Industry, Inc. (MSS)
MSS SP-44-2006, ``Steel Pipe Line Flanges'' (January 2006)
Replaces IBR: 1996 edition, reaffirmed 2001;
Referenced in 49 CFR 192.147(a).
NACE International (NACE)
NACE SP0169-2007, ``Control of External Corrosion on
Underground or Submerged Metallic Piping Systems''
Replaces IBR: NACE Standard RP0169-2002 ``Control of External
Corrosion on Underground or Submerged Metallic Piping Systems'';
Referenced in 49 CFR 195.571; 195.573.
NACE SP0502-2008 Standard Practice--Pipeline External
Corrosion Direct Assessment Methodology (Reaffirmed)
Replaces IBR: NACE Standard RP0502-2002 ``Pipeline External
Corrosion Direct Assessment Methodology'';
Referenced in 49 CFR 192.923(b)(1); 192.925(b) Introductory text;
192.925(b)(1); 192.925(b)(1)(ii); 192.925(b)(2) Introductory text;
192.925(b)(3) Introductory text; 192.925(b)(3)(ii); 192.925(b)(iv);
192.925(b)(4) Introductory text; 192.925(b)(4)(ii); 192.931(d);
192.935(b)(1)(iv); 192.939(a)(2); 195.588.
National Fire Protection Association (NFPA)
NFPA 30 (2008), ``Flammable and Combustible Liquids Code''
Replaces IBR: 2003 edition;
Referenced in 49 CFR 192.735(b); 195.264(b)(1).
NFPA 59A (2006), ``Standard for the Production, Storage,
and Handling of Liquefied Natural Gas (LNG)
Partially Replaces IBR: 2001 edition;
Referenced in 49 CFR 193.2101(b); 193.2321(b).
NFPA 70 (2008) ``National Electrical Code''
Replaces IBR: 2005 edition;
Referenced in 49 CFR 192.163(e); 192.189(c).
Plastics Pipe Institute, Inc. (PPI)
PPI TR-3/2008 (2008), ``Policies and Procedures for
Developing Hydrostatic Design Basis (HDB), Pressure Design Basis (PDB),
Strength Design Basis (SDB), and Minimum Required Strength (MRS)
Ratings for Thermoplastic Piping Materials or Pipe''
Replaces IBR: 2004 edition;
Referenced in 49 CFR 192.121.
On April 14, 2009 (74 FR 17099), PHMSA published a Direct Final
Rule that incorporated by reference the 2007 editions of API
Specification 5L ``Specification for Line Pipe'' and API 1104 ``Welding
of Pipelines and Related Facilities.'' That rulemaking did not
eliminate the use of the currently referenced standards but simply
allowed the additional use of these new standards. In this NPRM PHMSA
is proposing to eliminate the use of the previous editions of these
standards.
V. Clarifications, Corrections and Edits
This document proposes to revise the pipeline safety regulations to
make, non-substantive edits, update contact information, and provide
clarification as specified in the following section-by-section summary:
Part 192
Section 192.11
PHMSA is proposing to revise paragraph (c) in Sec. 192.11 to
require that Part 192 prevails if there is a conflict between Part 192
and NFPA 58 or 59 for the reasons discussed above in ``Updated
Standards Not Incorporated by Reference.''
Section 192.711
When the repair time conditions were implemented for
Pipeline Integrity Management in High Consequence Areas (HCA), this
section was not modified to clarify that the repair times for pipelines
covered by Sec. 192.711 pertained only to nonintegrity management
repairs.
We are revising this section to make that clearer.
Gas Piping Technology Committee (GPTC) Petition
GPTC is an accredited American National Standards Institute (ANSI)
standards committee that develops and publishes the ``Guide for Gas
Transmission and Distribution Piping Systems'', and assists natural gas
pipeline operators to comply with Part 192. PHMSA's Office of Pipeline
Safety (OPS) is represented on this committee. PHMSA proposes to make
the following amendments in response to a GPTC petition:
Sections 192.145(d) and 192.145(e)
Section 192.145 specifies the design and installation
requirements for valves. GPTC petition 89-04 requests that OPS clarify
the intent of Sec. 192.145(d) and (e) regarding the design
requirements for pressure containing parts of valves used in compressor
stations. OPS has several interpretations, PI-75-057 and PI-71-014,
stating that the plug or ball is not a pressure containing part. It is
OPS's intent to permit the use of cast iron plugs or balls in
combination with steel shell components.
We are proposing to revise paragraphs (d) and (e) to use the same
language as ANSI/ASME B31.8, paragraph 831.11(c) in referring to shell
components. Proposed revisions to paragraph (d) will clarify the
elements of a ``shell component.''
[[Page 36143]]
In response to GPTC's petition, we are also clarifying the
materials allowed in certain valve components used in compressor
stations. In paragraph (e), we are proposing to clarify that cast iron,
malleable iron, or ductile iron may be used in the valve ball or plug.
These materials may not be used in the pressure holding shell
components (body, bonnet, cover, or end flange).
Section 192.3
Section 192.3 defines terms used throughout Part 192.
PHMSA proposes to move the definitions, ``active corrosion'',
``electrical survey'' and ``pipeline environment'' from Sec.
192.465(e) to Sec. 192.3. This proposed revision will provide a
broader applicability of these terms to Part 192 because these terms
are also found in Part 192, Subparts I and O.
Section 192.557
GPTC petition 95-17 requests OPS revise Sec. 192.557(c) to allow
the use of a previous pressure test as a basis for increasing the
maximum allowable operating pressure (MAOP) of a steel pipeline that
will produce a hoop stress less than 30 percent of SMYS and of plastic,
cast iron, and ductile iron pipelines.
Regulations in Subpart K do not require a new pressure test be
conducted at the time of uprating unless the old pressure test cannot
justify the uprated pressure. Section 192.555 addresses uprating higher
stress steel pipelines and Sec. 192.557 addresses lower stress steel
pipelines and plastic, cast iron, and ductile iron pipelines. Section
192.555(c) explicitly allows the use of a previous pressure test as the
basis for establishing a higher MAOP. Since in Sec. 192.555(c), we
allow a previous pressure test at the higher level hoop stress, we
intended to allow it at a lower hoop stress in steel pipelines and in
plastic, cast iron, and ductile iron pipelines.
The confusion is with the requirement of Sec. 192.553(d), which
states that, ``* * * a new maximum allowable operating pressure
established under this subpart may not exceed the maximum that would be
allowed under this part for a new segment of pipeline constructed of
the same materials in the same location''. Only the derating for class
location as specified in Sec. 192.619 is a requirement of section
Sec. 192.553(d) for pipelines being uprated under Sec. 192.555(c).
The intent is not to preclude the use of a previous pressure test as a
basis for uprating. This requirement would also apply to steel
pipelines of lower hoop stress and to plastic, cast iron, and ductile
iron pipelines when the basis of uprating is a previous pressure test.
PHMSA proposes to clarify requirements for MAOP uprating in Sec.
192.557(c) by including the location factor requirements in Sec.
192.619(a)(2).
Part 193
Section 193.2101
PHMSA is proposing to revise this regulation to incorporate by
reference sections from the 2006 edition of NFPA59A pertaining to the
seismic design of stationary LNG storage tanks. Other sections from the
2001 edition of NFPA 59A would continue to be incorporated by reference
as designated in 193.2013. NFPA 59A (2006) incorporates by reference
the 1990 edition of API 620 but PHMSA proposes to incorporate by
reference the most recent version, API 620 (2008), for seismic design.
Section 193.2321
PHMSA is proposing to clarify the language in Sec. 193.2321(a) and
to use the broader terminology for non-destructive testing. PHMSA also
proposes to revise 193.2321(b) to add new requirements in accordance
with NFPA 59A's 2006 edition for the ultrasonic examination of LNG tank
welds for storage tanks with an internal design pressure at or below 15
psig.
Part 195
Section 195.307
PHMSA is proposing to revise paragraph (c) to reflect
revised section numbering regarding pneumatic testing from 5.3 to 5.2
of API Standard 650.
Section 195.401
When the repair time conditions were implemented for
Pipeline Integrity Management in High Consequence Areas (HCA), this
section was not modified to clarify that the repair times for pipelines
covered by Sec. 195.452 (pipelines that could affect an HCA) had to
comply with the integrity management repair requirements in Sec.
195.452(h). The requirement to repair a condition within a reasonable
time period (unless an immediate hazard) applies to conditions on
pipelines not covered by Sec. 195.452.
We are revising this section to make those requirements clearer.
Section 195.432
PHMSA is proposing to revise paragraph (b) to eliminate the
reference to section 4 in API Standard 653. All sections in API
Standard 653 relating to inspection of in-service atmospheric and low-
pressure steel aboveground breakout tanks are incorporated by
reference.
Section 195.452
PHMSA is proposing to revise paragraph (h)(4)(i) to
reflect new section numbering as specified in the updated ANSI/ASME
B31.4. The referenced section would be changed from ``451.7'' to
``451.6.2.2 (b)''.
VI. Rulemaking Analyses and Notices
Statutory/Legal Authority for This Rulemaking
This proposed rulemaking is published under the authority of the
Federal Pipeline Safety Law (49 U.S.C. 60101). Section 60102 authorizes
the Secretary of Transportation to issue regulations governing design,
installation, inspection, emergency plans and procedures, testing,
construction, extension, operation, replacement, and maintenance of
pipeline facilities. Section 60102(l) of the Federal Pipeline Safety
Law states that the Secretary shall, to the extent appropriate and
practicable, update incorporated industry standards that have been
adopted as part of the Federal pipeline safety regulations.
Privacy Act Statement
Anyone may search the electronic form of comments received in
response to any of our dockets by the name of the individual submitting
the comment (or signing the comment if submitted for an association,
business, labor union,). You may review DOT's complete Privacy Act
Statement in the Federal Register published on April 11, 2000 (65 FR
19477) or you may visit http://docketsinfo.dot.gov/.
Executive Order 13132
PHMSA has analyzed the proposed rulemaking according to the
principles and criteria in Executive Order 13132 (``Federalism''). The
proposed rule would not have a substantial direct effect on the States,
the relationship between the national government and the States, or the
distribution of power and responsibilities among the various levels of
government. The proposed rule would not impose substantial direct
compliance costs on State and local governments. This proposed
regulation would not preempt state law for intrastate pipelines.
Therefore, the consultation and funding requirements of Executive Order
13132 would not apply.
[[Page 36144]]
Executive Order 12866--Regulatory Planning and Review and DOT
Regulatory Policies and Procedures
This proposed rule is not a significant regulatory action under
section 3(f) of Executive Order 12866 (58 FR 51735) and, therefore,
would not be subject to review by the Office of Management and Budget.
This proposed rule is not significant under the Regulatory Policies and
Procedures of the Department of Transportation (44 FR 11034).
In this proposed rule we are updating references to standards that
are incorporated in the pipeline safety regulations. These updates will
enhance safety while reducing the compliance burden on the regulated
industry. We are also clarifying language in some of the provisions to
better reflect the intent of those regulations. Industry standards
developed and adopted by consensus generally are accepted and followed
by the industry; thus, their incorporation by reference in the Pipeline
Safety Regulations assures that the industry is not forced to comply
with a different set of standards to accomplish the same safety goal.
In addition, several amendments proposed for adoption provide
regulatory relief through compliance with certain nationally and
internationally recognized standards such as the American Society of
Mechanical Engineers (ASME) Boiler and Pressure Vessel Code and
standards published by the ASTM International (ASTM) and the American
Petroleum Institute (API). Requiring regulatory compliance with
standards such as the ASME, ASTM and API takes advantage of established
and well-defined and proven practices. Because we are proposing to
adopt industry consensus standards we expect compliance costs
associated with this proposal will be minimal.
Overall this proposed rule is intended to enhance transportation
safety and reduce the overall compliance burden on the regulated
industry. We invite public comment on any impacts of these proposed
amendments
Executive Order 13175
PHMSA has analyzed this proposed rulemaking according to Executive
Order 13175 (``Consultation and Coordination with Indian Tribal
Governments''). Because this proposed rulemaking would not
significantly or uniquely affect the communities of the Indian tribal
governments or impose substantial direct compliance costs, the funding
and consultation requirements of Executive Order 13175 would not apply.
Regulatory Flexibility Act
Under the Regulatory Flexibility Act (5 U.S.C. 601), PHMSA must
consider whether rulemaking actions would have a significant economic
impact on a substantial number of small entities. This proposed rule
would ensure that pipeline operators are using the most current
editions of technical standards incorporated by reference. The proposed
rule would also improve the clarity of several regulations. PHMSA
believes that this proposed rulemaking would impact a substantial
number of small entities but that this impact will be negligible. Based
on the facts available about the expected impact of this rulemaking, I
certify, under Section 605 of the Regulatory Flexibility Act (5 U.S.C.
605) that this proposed rulemaking will not have a significant economic
impact on a substantial number of small entities. PHMSA invites public
comments on this certification.
Unfunded Mandates Reform Act of 1995
This proposed rule would not impose unfunded mandates under the
Unfunded Mandates Reform Act of 1995. It would not result in costs of
$100 million (adjusted for inflation currently estimated to be $141
million) or more in any one year to either State, local, or tribal
governments, in the aggregate, or to the private sector, and would be
the least burdensome alternative that achieves the objective of the
proposed rulemaking.
Paperwork Reduction Act
This proposed rule would not impose any new information collection
requirements.
National Environmental Policy Act
The National Environmental Policy Act (42 U.S.C. 4321-4375)
requires that Federal agencies analyze proposed actions to determine
whether the action will have a significant impact on the human
environment. The Counsel on Environmental Quality (CEQ) regulations
order Federal agencies to conduct an environmental review considering
(1) the need for the proposed action (2) alternatives to the proposed
action (3) probable environmental impacts of the proposed action and
alternatives and (4) the agencies and persons consulted during the
consideration process. 40 CFR 1508.9(b).
1. Purpose and Need
PHMSA is proposing to incorporate by reference (IBR) into the
pipeline safety regulations all or parts of new editions of voluntary
consensus standards to allow pipeline operators to use current
technology, new materials, and other industry and management practices.
PHMSA also proposes to make non substantive edits and clarify
regulatory language in certain provisions. These proposed amendments to
the pipeline safety regulations would not require pipeline operators to
undertake any significant new pipeline safety initiatives.
2. Alternatives
In developing the proposed rule, we considered two alternatives:
(1) Do nothing.
(2) Propose revisions to the Pipeline Safety Regulations to
incorporate the newest editions of voluntary consensus standards to
allow pipeline operators to use current technologies.
Alternative 1
Because our goal is to facilitate uniformity, compliance, commerce
and safety in the transportation of hazardous liquids and gases by
pipeline, we rejected this alternative.
Alternative 2
Many of the industry standards currently incorporated by reference
have been revised and updated to incorporate new technology and
methodology. Most of the amendments would allow for alternative means
of compliance while still ensuring safety, clarify regulatory
requirements, and make the regulatory provisions more consistent--all
in furtherance of the safe transportation of hazardous materials by
pipeline.
3. Analysis of Environmental Impacts
The Nation's pipelines are located throughout the United States,
onshore and offshore, and traverse a variety of environments--from
highly populated urban sites to remote, unpopulated rural areas.\1\ .
The pipeline infrastructure is a network of over 2 million miles of
pipeline that moves millions of gallons of hazardous liquids and over
55 billion cubic feet of natural gas daily.\2\ The biggest source of
energy is petroleum, including oil and natural gas. Together, they
supply 65 percent of the energy in the United States.\3\
---------------------------------------------------------------------------
\1\ PHMSA, Pipeline Basics, http://primis.phmsa.dot.gov/comm/PipelineBasics.htm.
\2\ GAO/RCED-00-128, ``The Office of Pipeline Safety is Changing
How it Oversees the Pipeline Industry.''
\3\ PHMSA. Pipeline Safety Q&As.
---------------------------------------------------------------------------
The physical environment potentially affected by the proposed rule
includes the airspace, water resources (e.g., oceans, streams, lakes),
cultural and historical resources (e.g., properties
[[Page 36145]]
listed on the National Register of Historic Places), biological and
ecological resources (e.g., coastal zones, wetlands, plant and animal
species and their habitat, forests, grasslands, offshore marine
ecosystems), and special ecological resources (e.g., threatened and
endangered plant and animal species and their habitat, national and
State parklands, biological reserves, wild and scenic rivers) that
exist directly adjacent to and within the vicinity of pipelines.
Because the pipelines subject to the rule contain hazardous
materials, resources within the physically affected environment, as
well as public health and safety, may be affected by gas pipeline
incidents such as spills and leaks. Incidents on pipelines can result
in fires and explosions, with resulting damage to the local
environment. In addition, since pipelines often contain gas streams
laden with condensates and natural gas liquids (NGL's), failures also
result in spills of these liquids, which can cause environmental harm.
Depending on the size of a spill or gas leak, and the nature of the
impact zone, the environmental impacts could vary from property damage
and environmental damage to injuries or, on rare occasions, fatalities.
Updating the references to industry standards enhances safety and
environmental protection by recognizing the use of new technologies.
Thus it is possible that, on a national scale, the cumulative
environmental damage from pipelines is reduced, or at a minimum
unchanged.
Neither the ``do nothing'' alternative or the action alternative
would result in any significant impacts on the environment.
4. Consultations
Various industry associations and State regulatory agencies were
consulted in the development of this proposed rulemaking
5. Decision About the Degree of Environmental Impact
PHMSA has preliminarily determined that the selected alternative
would not have a significant impact on the human environment. PHMSA
welcomes comment on any of these conclusions.
Executive Order 13211
Transporting gas affects the nation's available energy supply.
However, this proposed rulemaking would not be a ``significant'' energy
action under Executive Order 13211. It also would not be a significant
regulatory action under Executive Order 12866 and would not be likely
to have a significant adverse effect on the supply, distribution, or
use of energy. Further, the Administrator of the Office of Information
and Regulatory Affairs would not be likely to identify this proposed
rule as a significant energy action.
Regulation Identifier Number (RIN)
A regulation identifier number (RIN) is assigned to each regulatory
action listed in the Unified Agenda of Federal Regulations. The
Regulatory Information Service Center publishes the Unified Agenda in
April and October of each year. The RIN number contained in the heading
of this document can be used to cross-reference this action with the
Unified Agenda.
List of Subjects
49 CFR Part 192
Incorporation by reference, Natural gas, Pipeline safety.
49 CFR Part 193
Incorporation by reference, Liquefied natural gas, Pipeline safety.
49 CFR Part 195
Anhydrous ammonia, Carbon dioxide, Incorporation by reference,
Petroleum pipeline safety.
In consideration of the foregoing, PHMSA proposes to amend 49 CFR
Parts 192, 193, and 195 as follows:
PART 192--TRANSPORTATION OF NATURAL AND OTHER GAS BY PIPELINE:
MINIMUM FEDERAL SAFETY STANDARDS
1. The authority citation for part 192 continues to read as
follows:
Authority: 49 U.S.C. 5103, 60102, 60104, 60108, 60109, 60110,
60113, 60116, 60118 and 60137; and 49 CFR 1.53.
2. In Sec. 192.3, add the following definitions for ``Active
corrosion'', ``Electrical survey'', and ``Pipeline environment'' in
appropriate alphabetical order as follows:
Sec. 192.3 Definitions.
* * * * *
Active corrosion means continuing corrosion that, unless
controlled, could result in a condition that is detrimental to public
safety.
* * * * *
Electrical survey means a series of closely spaced pipe-to-soil
readings over a pipeline which are subsequently analyzed to identify
locations where a corrosive current is leaving the pipeline.
* * * * *
Pipeline environment includes soil resistivity (high or low), soil
moisture (wet or dry), soil contaminants that may promote corrosive
activity, and other known conditions that could affect the probability
of active corrosion.
* * * * *
3. In Sec. 192.7, revise paragraph (c)(2) to read as follows:
Sec. 192.7 What documents are incorporated by reference partly or
wholly in this part?
* * * * *
(c) * * *
(2) Documents incorporated by reference.
------------------------------------------------------------------------
Source and name of referenced
material 49 CFR reference
------------------------------------------------------------------------
A. Pipeline Research Council
International (PRCI):
(1) AGA Pipeline Research Sec. Sec. 192.933(a)(1);
Committee, Project PR-3-805, 192.933(d)(1)(i); 192.485(c).
``A Modified Criterion for
Evaluating the Remaining
Strength of Corroded Pipe,''
(December 22, 1989). The
RSTRENG program may be used
for calculating remaining
strength.
B. American Petroleum Institute
(API):
(1) ANSI/API Specification 5L/ Sec. Sec. 192.55(e); 192.113;
ISO 3183, ``Specification for Item I of Appendix B.
Line Pipe'' (44th edition,
2007), Includes Errata and
Addendum (2009).
(2) API Recommended Practice Sec. 192.65(a).
5L1, ``Recommended Practice
for Railroad Transportation of
Line Pipe'' (6th edition,
2002).
(3) API Recommended Practice Sec. 192.65(b).
5LW, ``Recommended Practice
for ``Transportation of Line
Pipe on Barges and Marine
Vessels'' (2nd edition, 1996).
(4) API Specification 6D/ISO Sec. 192.145(a)
14313, ``Pipeline Valves''
(23rd edition and errata 1, 2
and 3, (2009).
[[Page 36146]]
(5) API Recommended Practice Sec. Sec. 192.8(a); 192.8(a)(1);
80, ``Guidelines for the 192.8(a)(2); 192.8(a)(3);
Definition of Onshore Gas 192.8(a)(4).192.8(a); 192.8(a)(1);
Gathering Lines,'' (1st 192.8(a)(2); 192.8(a)(3);
edition, April 2000). 192.8(a)(4).
(6) API 1104, ``Welding of Sec. Sec. 192.225; 192.227(a);
Pipelines and Related 192.229(c)(1);
Facilities'' (20th edition, 192.241(c); Item II, Appendix B.
Errata/Addendum, (2007) and
Errata 2 (2008)).
(7) API Recommended Practice Sec. Sec. 192.616(a);
1162, ``Public Awareness 192.616(b); 192.616(c).
Programs for Pipeline
Operators'' (1st edition,
December 2003).
C. American Society for Testing and
Materials (ASTM):
(1) ASTM A53/A53M-07, (2007), Sec. Sec. 192.113; Item I,
``Standard Specification for Appendix B.
Pipe, Steel, Black and Hot-
Dipped, Zinc-Coated, Welded
and Seamless.''.
(2) ASTM A106/A106M-08, (2008), Sec. Sec. 192.113; Item I,
``Standard Specification for Appendix B.
Seamless Carbon Steel Pipe for
High-Temperature Service''.
(3) ASTM A333/A333M-05 (2005) Sec. Sec. 192.113; Item I,
``Standard Specification for Appendix B.
Seamless and Welded Steel Pipe
for Low-Temperature Service''.
(4) ASTM A372/A372M-03 (2008), Sec. 192.177(b)(1).
``Standard Specification for
Carbon and Alloy Steel
Forgings for Thin-Walled
Pressure Vessels''.
(5) ASTM A381-96 (Reapproved Sec. Sec. 192.113; Item I,
2005), ``Standard Appendix B.
Specification for Metal-Arc
Welded Steel Pipe for Use With
High-Pressure Transmission
Systems''.
(6) ASTM A671-06, (2006), Sec. Sec. 192.113; Item I,
``Standard Specification for Appendix B.
Electric-Fusion-Welded Steel
Pipe for Atmospheric and Lower
Temperatures''.
(7) ASTM A672-08, (2008), Sec. Sec. 192.113; Item I,
``Standard Specification for Appendix B.
Electric-Fusion-Welded Steel
Pipe for High-Pressure Service
at Moderate Temperatures''.
(8) ASTM A691-98 (Reapproved Sec. Sec. 192.113; Item I,
2007), ``Standard Appendix B.
Specification for Carbon and
Alloy Steel Pipe, Electric-
Fusion-Welded for High-
Pressure Service at High
Temperatures''.
(9) ASTM D638-03, ``Standard Sec. Sec. 192.283(a)(3);
Test Method for Tensile 192.283(b)(1).
Properties of Plastics''.
(10) ASTM D2513-87, ``Standard Sec. 192.63(a)(1).
Specification for
Thermoplastic Gas Pressure
Pipe, Tubing, and Fittings''.
(11) ASTM D2513-99, ``Standard Sec. Sec. 192.191(b);
Specification for 192.281(b)(2); 192.283(a)(1)(i);
Thermoplastic Gas Pressure Item 1, Appendix B.
Pipe, Tubing, and Fittings''.
(12) ASTM D2517-00, ``Standard Sec. Sec. 192.191(a);
Specification for Reinforced 192.281(d)(1); 192.283(a)(1)(ii);
Epoxy Resin Gas Pressure Pipe Item I,
and Fittings''. Appendix B.
(13) ASTM F1055-1998, Sec. 192.283(a)(1)(iii).
``Standard Specification for
Electrofusion type
Polyethylene Fittings for
Outside Diameter Controller
Polyethylene Pipe and Tubing''.
D. ASME International (ASME):
(1) ANSI/ASME B16.1-2005, Gray Sec. 192.147(c).
Iron Pipe Flanges and Flanged
Fittings: Classes 25, 125, and
250.
(2) ANSI/ASME B16.5-2003, Sec. Sec. 192.147(a); 192.279.
``Pipe Flanges and Flanged
Fittings 1998''.
(3) ANSI/ASME B31G-1991 Sec. Sec. 192.485(c);
(Reaffirmed; 2004), ``Manual 192.933(a).
for Determining the Remaining
Strength of Corroded
Pipelines''.
(4) ANSI/ASME B31.8-2007, Sec. 192.619(a)(1)(i).
(November 2007), ``Gas
Transmission and Distribution
Piping Systems''.
(5) ANSI/ASME B31.8S-2004, Sec. Sec. 192.903(c);
``Supplement to B31.8 on 192.907(b); 192.911, Introductory
Managing System Integrity of text; 192.911(i); 192.911(k);
Gas Pipelines''. 192.911(l); 192.911(m); 192.913(a)
Introductory text; 192.913(b)(1);
192.917(a) Introductory text;
192.917(b); 192.917(c);
192.917(e)(1); 192.917(e)(4);
192.921(a)(1); 192.923(b)(1);
192.923(b)(2); 192.923(b)(3);
192.925(b) Introductory text;
102.925(b)(1); 192.925(b)(2);
192.925(b)(3); 192.925(b)(4);
192.927(b); 192.927(c)(1)(i);
192.929(b)(1); 192.929(b)(2);
192.933(a); 192.933(d)(1);
192.933(d)(1)(i); 192.935(a);
192.935(b)(1)(iv); 192.937(c)(1);
192.939(a)(1)(i);
192.939(a)(1)(ii); 192.939(a)(3);
192.945(a).
(6) ASME Boiler and Pressure Sec. 192.153(b).
Vessel Code, Section I,
``Rules for Construction of
Power Boilers'' (2007 edition).
(7) ASME Boiler and Pressure Sec. Sec. 192.153(a);
Vessel Code, Section VIII, 192.153(b); 192.153(d);
Division 1, ``Rules for 192.165(b)(3).
Construction of Pressure
Vessels'' (2007 edition).
(8) ASME Boiler and Pressure Sec. Sec. 192.153(b);
Vessel Code, Section VIII, 192.165(b)(3).
Division 2, ``Rules for
Construction of Pressure
Vessels'' (2007 edition).
(9) ASME Boiler and Pressure Sec. Sec. 192.227(a); Item II,
Vessel Code, Section IX, Appendix B.
``Welding and Brazing
Qualifications'' (2007
edition).
E. Manufacturers Standardization
Society of the Valve and Fittings
Industry, Inc. (MSS):
(1) MSS SP-44-2006 ``Steel Pipe Sec. 192.147(a).
Line Flanges''.
(2) [Reserved]................. ...................................
F. National Fire Protection
Association (NFPA):
(1) NFPA 30 (2008), ``Flammable Sec. 192.735(b).
and Combustible Liquids Code''.
(2) NFPA 58 (2004), ``Liquefied Sec. Sec. 192.11(a); 192.11(b);
Petroleum Gas Code (LP-Gas 192.11(c).
Code)''.
[[Page 36147]]
(3) NFPA 59 (2004), ``Utility Sec. Sec. 192.11(a); 192.11(b);
LP-Gas Plant Code''. 192.11(c).
(4) NFPA 70 (2008), ``National Sec. Sec. 192.163(e);
Electrical Code''. 192.189(c).
G. Plastics Pipe Institute, Inc.
(PPI):
(1) PPI TR-3/2008 (2008), Sec. 192.121.
``Policies and Procedures for
Developing.
Hydrostatic Design Basis (HDB),
Pressure Design Basis (PDB),
Strength Design Basis (SDB),
and Minimum Required Strength
(MRS) Ratings for
Thermoplastic Piping Materials
or Pipe''.
H. NACE International (NACE):
(1) NACE Standard SP0502-2008, Sec. Sec. 192.923(b)(1);
``Pipeline External Corrosion 192.925(b) Introductory text;
Direct Assessment 192.925(b)(1); 192.925(b)(1)(ii);
Methodology''. 192.925(b)(2) Introductory text;
192.925(b)(3) Introductory text;
192.925(b)(3)(ii); 192.925(b)(iv);
192.925(b)(4) Introductory text;
192.925(b)(4)(ii); 192.931(d);
192.935(b)(1)(iv); 192.939(a)(2).
I. Gas Technology Institute (GTI):
(1) GRI 02/0057 (2002), Sec. 192.927(c)(2).
``Internal Corrosion Direct
Assessment of Gas Transmission
Pipelines Methodology''.
------------------------------------------------------------------------
4. In Sec. 192.11, revise paragraph (c) to read as follows:
Sec. 192.11 Petroleum gas systems.
* * * * *
(c) If there is a conflict between this part and NFPA 58 or NFPA
59, this part prevails.
5. Section 192.65 is revised to read as follows:
Sec. 192.65 Transportation of pipe.
(a) Railroad. In a pipeline to be operated at a hoop stress of 20
percent or more of SMYS, an operator may not use pipe having an outer
diameter to wall thickness ratio of 70 to 1, or more, that is
transported by railroad unless:
(1) The transportation is performed in accordance with API RP 5L1
(incorporated by reference, see Sec. 192.3).
(2) In the case of pipe transported before November 12, 1970, the
pipe is tested in accordance with Subpart J of this part to at least
1.25 times the maximum allowable operating pressure if it is to be
installed in a class 1 location and to at least 1.5 times the maximum
allowable operating pressure if it is to be installed in a class 2, 3,
or 4 location. Notwithstanding any shorter time period permitted under
Subpart J of this part, the test pressure must be maintained for at
least 8 hours.
(b) Ship or barge. In a pipeline to be operated at a hoop stress of
20 percent or more of SMYS, an operator may not use pipe having an
outer diameter to wall thickness ratio of 70 to 1, or more, that is
transported by ship or barge on both inland and marine waterways unless
the transportation is performed in accordance with API RP 5LW.
Sec. 192.121 [Amended]
6. In Sec. 192.121, under ``S='', remove the term ``PPI TR-3/
2004'' and add, in its place, the term ``PPI TR-3/2008''.
7. In Sec. 192.145, revise the first sentence in paragraph (d)
introductory text and paragraph (e) to read as follows:
Sec. 192.145 Valves.
* * * * *
(d) No valve having shell (body, bonnet, cover, and/or end flange)
components made of ductile iron may be used at pressures exceeding 80
percent of the pressure ratings for comparable steel valves at their
listed temperature. * * *
* * * * *
(e) No valve having shell (body, bonnet, cover, and/or end flange)
components made of cast iron, malleable iron, or ductile iron may be
used in the gas pipe components of compressor stations.
8. In Sec. 192.465, revise paragraph (e) to read as follows:
Sec. 192.465 External corrosion control: Monitoring.
* * * * *
(e) After the initial evaluation required by Sec. Sec. 192.455(b)
and (c) and 192.457(b), each operator must, not less than every 3 years
at intervals not exceeding 39 months, reevaluate its unprotected
pipelines and cathodically protect them in accordance with this subpart
in areas in which active corrosion is found. The operator must
determine the areas of active corrosion by electrical survey. However,
on distribution lines and where an electrical survey is impractical on
transmission lines, areas of active corrosion may be determined by
other means that include review and analysis of leak repair and
inspection records, corrosion monitoring records, exposed pipe
inspection records, and the pipeline environment.
9. In Sec. 192.557, revise paragraph (c) to read as follows:
Sec. 192.557 Uprating: Steel pipelines to a pressure that will
produce a hoop stress less than 30 percent of SMYS: plastic, cast iron,
and ductile iron pipelines.
* * * * *
(c) Notwithstanding the requirements of Sec. 192.619(a)(2), and
after complying with paragraph (b) of this section, the increase in
maximum allowable operating pressure (MAOP) must be made in increments
that are equal to 10 psig (69 kPa) or 25 percent of the total pressure
increase, whichever produces the fewer number of increments. Whenever
the requirements of paragraph (b)(6) of this section apply, there must
be at least two approximately equal incremental increases.
* * * * *
10. Section 192.711 is revised to read as follows:
Sec. 192.711 Transmission lines: General requirements for repair
procedures.
(a) Temporary repairs. Each operator must take immediate temporary
measures to protect the public whenever:
(1) A leak, imperfection, or damage that impairs its serviceability
is found in a segment of steel transmission line operating at or above
40 percent of the SMYS; and
(2) It is not feasible to make a permanent repair at the time of
discovery.
(b) Permanent repairs. An operator must make permanent repairs on
its pipeline system according to the following:
(1) Non integrity management repairs: The operator must make
permanent repairs as soon as feasible.
(2) Integrity management repairs: When an operator discovers a
condition
[[Page 36148]]
on a pipeline covered under Subpart O-Gas Transmission Pipeline
Integrity Management, the operator must remediate the condition as
prescribed by Sec. 192.933(d).
(c) Welded patch. Except as provided in Sec. 192.717(b)(3), no
operator may use a welded patch as a means of repair.
Sec. Sec. 192.923, 192.925, 192.931, 192.935, and 192.939 [Amended]
11. In 49 CFR part 192 remove the terms ``NACE RP0502-2002'' or
``NACE RP 0502-2002''and add, in their place, the terms ``NACE SP0502-
2008'' in the following places:
a. Section 192.923(b)(1);
b. Section 192.925(b) Introductory text, (b)(1), (b)(1)(ii), (b)(2)
Introductory text, (b)(3) Introductory text, (b)(3)(ii), (b)(iv),
(b)(4) Introductory text, (b)(4)(ii);
c. Section 192.931(d);
d. Section 192.935(b)(1)(iv); and
e. Section 192.939(a)(2).
PART 193--LIQUEFIED NATURAL GAS FACILITIES: FEDERAL SAFETY
STANDARDS
12. The authority citation for part 193 continues to read as
follows:
Authority: 49 U.S.C. 5103, 60102, 60103, 60104, 60108, 60109,
60110, 60113, 60118; and 49 CFR 1.53.
13. In Sec. 193.2013, revise paragraph (c), to read as follows:
Sec. 193.2013 Incorporation by reference.
* * * * *
(c) Documents incorporated by reference.
------------------------------------------------------------------------
Source and name of referenced
material 49 CFR reference
------------------------------------------------------------------------
A. American Gas Association (AGA):
(1) ``Purging Principles and Sec. Sec. 193.2513; 193.2517;
Practices'' (3rd edition, 193.2615.
2001).
B. American Petroleum Institute
(API):
(1) API 620 (2008), ``Design Sec. Sec. 193.2101(b);
and Construction of Large, 193.2321(b).
Welded, Low-Pressure Storage
Tanks'' (11th edition, 2008).
C. American Society of Civil
Engineers (ASCE):
(1) ASCE/SEI 7-05, ``Minimum Sec. 193.2067.
Design Loads for Buildings and
Other Structures'' (2005
edition).
D. ASME International (ASME):
(1) ASME Boiler and Pressure Sec. Sec. 193.2321; 193.2321.
Vessel Code, Section VIII,
Division 1, ``Rules for
Construction of Pressure
Vessels'' (2007 edition).
E. Gas Technology Institute (GTI)
formerly the Gas Research
Institute (GRI):
(1) GTI-04/0032, ``LNGFIRE: A Sec. 193.2057(a).
Thermal Radiation Model for
LNG Fires''.
(2) GTI-04/0049, ``LNG Vapor Sec. 193.2059.
Dispersion Prediction with the
DEGADIS Dense Gas Dispersion
Model'' (April 2004).
(3) GRI-96/0396.5, ``Evaluation Sec. 193.2059.
of Mitigation Methods for
Accidental LNG Releases,
Volume 5: Using FEM3A for LNG
Accident Consequence
Analyses'' (April 1997).
F. National Fire Protection
Association (NFPA):
(1) NFPA 59A, ``Standard for Sec. Sec. 193.2019; 193.2051;
the Production, Storage, and 193.2057; 193.2059; 193.2101(a);
Handling of Liquefied Natural 193.2301; 193.2303; 193.2401;
Gas (LNG)'' (2001 edition). 193.2521; 193.2639; 193.2801.
(2) NFPA 59A, ``Standard for Sec. Sec. 193.2101(b);
the Production, Storage, and 193.2321(b).
Handling of Liquefied Natural
Gas (LNG)'' (2006 edition).
------------------------------------------------------------------------
14. In Sec. 193.2057, revise paragraph (a) to read as follows:
Sec. 193.2057 Thermal radiation protection.
* * * * *
(a) The thermal radiation distances must be calculated using Gas
Technology Institute's (GTI) report or computer model GTI-04/0032
LNGFIRE3: A Thermal Radiation Model for LNG Fires (incorporated by
reference, see Sec. 193.2013). The use of other alternate models which
take into account the same physical factors and have been validated by
experimental test data may be permitted subject to the Administrator's
approval.
* * * * *
15. In Sec. 193.2067, revise paragraph (b)(1) to read as follows:
Sec. 193.2067 Wind forces.
* * * * *
(b) * * *
(1) For shop fabricated containers of LNG or other hazardous fluids
with a capacity of not more than 70,000 gallons, applicable wind load
data in ASCE/SEI 7-05 (incorporated by reference, see Sec. 193.2013).
* * * * *
16. Section 193.2101 is revised to read as follows:
Sec. 193.2101 Scope.
(a) Each LNG facility designed after March 31, 2000 must comply
with requirements of this part and of NFPA 59A (2001) (incorporated by
reference, see Sec. 193.2013). If there is a conflict between this
part and NFPA 59A, this part prevails. Unless otherwise specified, all
references to NFPA 59A in this part are to the 2001 edition.
(b) Stationary LNG storage tanks must comply with section 7.2.2 of
NFPA 59A (2006) (incorporated by reference, see Sec. 193.2013) for
seismic design of field fabricated tanks. All other LNG storage tanks
must comply with API 620 (2008) (incorporated by reference, see Sec.
193.2013) for seismic design.
17. Section 193.2321 is revised to read as follows:
Sec. 193.2321 Nondestructive tests.
(a) The butt welds in metal shells of storage tanks with internal
design pressure above 15 psig must be non-destructively examined in
accordance with the ASME Boiler and Pressure Vessel Code (Section VIII
Division 1) (incorporated by reference, see Sec. 193.2013), except
that 100 percent of welds that are both longitudinal (or meridional)
and circumferential (or latitudinal) of hydraulic load bearing shells
with curved surfaces that are subject to cryogenic temperatures must be
non-destructively examined in accordance with the ASME Boiler and
Pressure Vessel Code (Section VIII Division 1).
(b) For storage tanks with internal design pressures at 15 psig or
less,
[[Page 36149]]
ultrasonic examinations of welds on metal containers must comply with
the following:
(1) Section 7.3.1.2 of NFPA 59A (2006) (incorporated by reference,
see Sec. 193.2013);
(2) Appendices Q and C of API 620 (2008) (incorporated by
reference, see Sec. 193.2013);
(c) Ultrasonic examination records must be retained for the life of
the facility. If electronic records are kept, they must be retained in
a manner so that they cannot be altered by any means; and
(d) The ultrasonic equipment used in the examination of welds must
be calibrated at a frequency no longer than eight hours. Such
calibrations must verify the examination of welds against a calibration
standard. If the ultrasonic equipment is found to be out of
calibration, all previous weld inspections that are suspect must be
reexamined.
PART 195--TRANSPORTATION OF HAZARDOUS LIQUIDS BY PIPELINE
18. The authority citation for part 195 continues to read as
follows:
Authority: 49 U.S.C. 5103, 60102, 60104, 60108, 60109, 60116,
60118 and 60137; and 49 CFR 1.53.
19. In Sec. 195.3, revise paragraph (c) to read as follows:
Sec. 195.3 Incorporation by reference.
* * * * *
(c) The full titles of publications incorporated by reference
wholly or partially in this part are as follows. Numbers in parentheses
indicate applicable editions:
------------------------------------------------------------------------
Source and name of referenced
material 49 CFR reference
------------------------------------------------------------------------
A. Pipeline Research Council
International, Inc. (PRCI):
(1) AGA Pipeline Research Sec. Sec. 195.452(h)(4)(i)(B);
Committee, Project PR-3-805, 195.452(h)(4)(iii)(D); 195.587.
``A Modified Criterion for
Evaluating the Remaining
Strength of Corroded Pipe,''
(December 22, 1989). The
RSTRENG program may be used
for calculating remaining
strength.
B. American Petroleum Institute
(API):
(1) ANSI/API Specification 5L/ Sec. Sec. 195.106(b)(1)(i);
ISO 3183, ``Specification for 195.106(e).
Line Pipe'' (44th edition,
2007), Includes Errata and
Addendum (2009).
(2) API Recommended Practice Sec. 195.207.
5L1, ``Recommended Practice
for Railroad Transportation of
Line Pipe'' (6th edition,
2002).
(3) API Recommended Practice Sec. 195.207.
5LW, ``Recommended Practice
for ``Transportation of Line
Pipe on Barges and Marine
Vessels'' (2nd edition, 1996).
(4) API Specification 6D/ISO Sec. 195.116(d).
14313, ``Pipeline Valves''
(23rd edition and errata 1, 2,
and 3,(2009).
(5) ANSI/API 12F, Errata for Sec. Sec. 195.132(b)(1);
``Specification for Shop 195.205(b)(2); 195.264(b)(1);
Welded Tanks for Storage of 195.264(e)(1); 195.307(a);
Production Liquids'' (12th 195.565; 195.579(d).
edition, 2007).
(6) ANSI/API 510, ``Pressure Sec. Sec. 195.205(b)(3);
Vessel Inspection Code: 195.432(c).
Maintenance Inspection,
Rating, Repair, and
Alteration'' (9th edition,
2006).
(7) API 620, ``Design and Sec. Sec. 195.132(b)(2);
Construction of Large, Welded, 195.205(b)(2); 195.264(b)(1);
Low-Pressure Storage Tanks'' 195.264(e)(3); 195.307(b).
(11th edition, 2008, Addendum
1, 2009).
(8) API 650, ``Welded Steel Sec. Sec. 195.132(b)(3);
Tanks for Oil Storage'' (11th 195.205(b)(1); 195.264(b)(1);
edition, 2007, Addendum, 2008). 195.264(e)(2); 195.307(c);
195.307(d); 195.565; 195.579(d).
(9) ANSI/API Recommended Sec. Sec. 195.565; 195.579(d).
Practice 651, ``Cathodic
Protection of Aboveground
Petroleum Storage Tanks'' (3rd
edition, January 2007).
(10) ANSI/API Recommended Sec. 195.579(d).
Practice 652, ``Lining of
Aboveground Petroleum Storage
Tank Bottoms'' (3rd edition,
October 2005).
(11) API 653, ``Tank Sec. Sec. 195.205(b)(1);
Inspection, Repair, 195.432(b).
Alteration, and
Reconstruction'' (3rd edition
Third Edition, Includes
Addendum 1 (2003), Addendum 2
(2005), Addendum 3 (2008), and
Errata (2008), April 2008).
(12) API 1104, ``Welding of Sec. Sec. 195.222; 195.228(b);
Pipelines and Related 195.214(a).
Facilities'' (20th edition,
Errata/Addendum, (2007) and
Errata 2 (2008)).
(13) API 1130, ``Computational Sec. Sec. 195.134; 195.444.
Pipeline Monitoring for Liquid
Pipelines'' (1st edition,
2007).
(14) API 2000, ``Venting Sec. Sec. 195.264(e)(2);
Atmospheric and Low-Pressure 195.264(e)(3).
Storage Tanks'' (5th edition,
errata, Nov. 1999).
(15) API Recommended Practice Sec. 195.405(a).
2003, ``Protection Against
Ignitions Arising Out of
Static, Lightning, and Stray
Currents'' (7th edition, 2008).
(16) API 2026, ``Safe Access/ Sec. 195.405(b).
Egress Involving Floating
Roofs of Storage Tanks in
Petroleum Service'' (2nd
edition with reaf, 2006).
(17) API Recommended Practice Sec. 195.428(c).
2350, ``Overfill Protection
for Storage Tanks In Petroleum
Facilities''' (3rd edition,
2005).
(18) API 2510, ``Design and Sec. Sec. 195.132(b)(3);
Construction of LPG 195.205(b)(3); 195.264(b)(2);
Installations'' (8th edition, 195.264(e)(4);
2001). 195.307(e);195.428(c); 195.432(c).
(19) API Recommended Practice Sec. Sec. 195.440(a);
1162, ``Public Awareness 195.440(b); 195.440(c).
Programs for Pipeline
Operators'' (1st edition,
December 2003).
C. ASME International (ASME):
[[Page 36150]]
(1) ANSI/ASME B16.9-2007 Sec. 195.118(a).
(December 2007), ``Factory-
Made Wrought Steel Butt
Welding Fittings''.
(2) ANSI/ASME B31.4-2006) Sec. 195.452(h)(4)(i).
(October 2006), ``Pipeline
Transportation Systems for
Liquid Hydrocarbons and Other
Liquids''.
(3) ANSI/ASME B31G-1991 Sec. Sec. 195.452(h)(4)(i)(B);
(Reaffirmed; 2004), ``Manual 195.452(h)(4)(iii)(D).
for Determining the Remaining
Strength of Corroded
Pipelines''.
(4) ANSI/ASME B31.8-2007 Sec. Sec. 195.5(a)(1)(i);
(November 2007), ``Gas 195.406(a)(1)(i).
Transmission and Distribution
Piping Systems''.
(5) ASME Boiler and Pressure Sec. Sec. 195.124; 195.307(e).
Vessel Code, Section VIII,
Division 1, ``Rules for
Construction of Pressure
Vessels,'' (2007 edition, July
1, 2007).
(6) ASME Boiler and Pressure Sec. 195.307(e).
Vessel Code, Section VIII,
Division 2, ``Alternate Rules
for Construction for Pressure
Vessels'' (2007 edition, July
1, 2007).
(7) ASME Boiler and Pressure Sec. 195.222.
Vessel Code, Section IX,
``Welding and Brazing
Qualifications,'' (2007
edition, July 1, 2007).
D. Manufacturers Standardization
Society of the Valve and Fittings
Industry, Inc. (MSS):
(1) MSS SP-75-2004, Sec. 195.118(a).
``Specification for High Test
Wrought Butt Welding
Fittings'' (1993).
(2) [Reserved].................
E. American Society for Testing and
Materials (ASTM):
(1) ASTM A53/A53M-07 (2007), Sec. 195.106(e).
``Standard Specification for
Pipe, Steel, Black and Hot-
Dipped, Zinc-Coated Welded and
Seamless''.
(2) ASTM A106/A106M-08 (2008), Sec. 195.106(e).
``Standard Specification for
Seamless Carbon Steel Pipe for
High-Temperature Service''.
(3) ASTM A333/A 333M-05 (2004), Sec. 195.106(e).
``Standard Specification for
Seamless and Welded Steel Pipe
for Low-Temperature Service''.
(4) ASTM A381-96 (Reapproved Sec. 195.106(e).
2005), ``Standard
Specification for Metal-Arc-
Welded Steel Pipe for Use With
High-Pressure Transmission
Systems''.
(5) ASTM A671-06 (2006), Sec. 195.106(e).
``Standard Specification for
Electric-Fusion-Welded Steel
Pipe for Atmospheric and Lower
Temperatures''.
(6) ASTM A672-08 (2008), Sec. 195.106(e).
``Standard Specification for
Electric-Fusion-Welded Steel
Pipe for High-Pressure Service
at Moderate Temperatures''.
(7) ASTM A691-98 (2007), Sec. 195.106(e).
``Standard Specification for
Carbon and Alloy Steel Pipe
Electric-Fusion-Welded for
High-Pressure Service at High
Temperatures''.
F. National Fire Protection
Association (NFPA):
(1) NFPA 30 (2008), ``Flammable Sec. 195.264(b)(1).
and Combustible Liquids Code''.
(2) [Reserved].................
G. NACE International (NACE):
(1) NACE Standard SP0169-2007, Sec. Sec. 195.571; 195.573.
``Control of External
Corrosion on Underground or
Submerged Metallic Piping
Systems''.
(2) NACE Standard SP0502-2008, Sec. 195.588.
``Pipeline External Corrosion
Direct Assessment
Methodology''.
------------------------------------------------------------------------
20. In Sec. 195.116, revise paragraph (d) to read as follows:
Sec. 195.116 Valves.
* * * * *
(d) Each valve must be both hydrostatically shell tested and
hydrostatically seat tested without leakage to at least the
requirements set forth in section 11 of API Standard 6D (incorporated
by reference, see Sec. 195.3).
* * * * *
21. Add Sec. 195.207 to subpart D to read as follows:
Sec. 195.207 Transportation of pipe.
(a) Railroad. In a pipeline operated at a hoop stress of 20 percent
or more of SMYS, an operator may not use pipe having an outer diameter
to wall thickness ratio of 70 to 1, or more, that is transported by
railroad unless the transportation is performed in accordance with API
RP 5L1 (incorporated by reference, see Sec. 195.3).
(b) Ship or barge. In a pipeline operated at a hoop stress of 20
percent or more of SMYS, an operator may not use pipe having an outer
diameter to wall thickness ratio of 70 to 1, or more, that is
transported by ship or barge on both inland and marine waterways,
unless the transportation is performed in accordance with API RP 5LW
(incorporated by reference, see Sec. 195.3).
22. In Sec. 195.307, revise paragraph (c) to read as follows:
Sec. 195.307 Pressure testing aboveground breakout tanks.
* * * * *
(c) For aboveground breakout tanks built to API Standard 650 and
first placed in service after October 2, 2000, testing must be in
accordance with section 5.2 of API Standard 650 (incorporated by
reference, see Sec. 195.3).
* * * * *
23. In Sec. 195.401, paragraph (b) is revised to read as follows:
Sec. 195.401 General requirements.
* * * * *
(b) An operator must make repairs on its pipeline system according
to the following requirements:
[[Page 36151]]
(1) Non Integrity management repairs. Whenever an operator
discovers any condition that could adversely affect the safe operation
of its pipeline system, it must correct the condition within a
reasonable time. However, if the condition is of such a nature that it
presents an immediate hazard to persons or property, the operator may
not operate the affected part of the system until it has corrected the
unsafe condition.
(2) Integrity management repairs. When an operator discovers a
condition on a pipeline covered under Sec. 195.452, the operator must
correct the condition as prescribed in Sec. 195.452 (h).
* * * * *
24. In Sec. 195.432, paragraph (b) is revised to read as follows:
Sec. 195.432 Inspection of in-service breakout tanks.
* * * * *
(b) Each operator must inspect the physical integrity of in-service
atmospheric and low-pressure steel aboveground breakout tanks according
to API Standard 653 (incorporated by reference, see Sec. 195.3).
However, if structural conditions prevent access to the tank bottom,
the bottom integrity may be assessed according to a plan included in
the operations and maintenance manual under Sec. 195.402(c)(3).
* * * * *
25. In Sec. 195.452, paragraphs (h)(4)(i) introductory text is
revised to read as follows:
Sec. 195.452 Pipeline integrity management in high consequence areas.
* * * * *
(h) * * *
(4) * * *
(i) Immediate repair conditions. An operator's evaluation and
remediation schedule must provide for immediate repair conditions. To
maintain safety, an operator must temporarily reduce operating pressure
or shut down the pipeline until the operator completes the repair of
these conditions. An operator must calculate the temporary reduction in
operating pressure using the formula in section 451.6.2.2(b) of ANSI/
ASME B31.4 (incorporated by reference, see Sec. 195.3). An operator
must treat the following conditions as immediate repair conditions:
* * * * *
26. Section 195.571 is revised to read as follows:
Sec. 195.571 What criteria must I use to determine the adequacy of
cathodic protection?
Cathodic protection required by this subpart must comply with one
or more of the applicable criteria and other considerations for
cathodic protection contained in paragraphs 6.2 and 6.3 of NACE SP 0169
(incorporated by reference, see Sec. 195.3).
27. In Sec. 195.573, paragraph (a)(2) is revised to read as
follows:
Sec. 195.573 What must I do to monitor external corrosion control?
(a) * * *
(2) Identify not more than 2 years after cathodic protection is
installed, the circumstances in which a close-interval survey or
comparable technology is practicable and necessary to accomplish the
objectives of paragraph 10.1.1.3 of NACE SP 0169 (incorporated by
reference, see Sec. 195.3).
* * * * *
28. In Sec. 195.588, paragraphs (b)(1), (b)(2) introductory text,
(b)(2)(iii), (b)(3) introductory text, (b)(4) introductory text,
(b)(4)(ii), (b)(4)(iv), (b)(5) introductory text, and (b)(5)(ii) are
revised to read as follows:
Sec. 195.588 What standards apply to direct assessment?
* * * * *
(b) * * *
(1) General. You must follow the requirements of NACE SP0502
(incorporated by reference, see Sec. 195.3). Also, you must develop
and implement an ECDA plan that includes procedures addressing pre-
assessment, indirect examination, direct examination, and post-
assessment.
(2) Pre-assessment. In addition to the requirements in Section 3 of
NACE SP0502, the ECDA plan procedures for pre-assessment must include--
* * * * *
(iii) If you utilize an indirect inspection method not described in
Appendix A of NACE SP0502, you must demonstrate the applicability,
validation basis, equipment used, application procedure, and
utilization of data for the inspection method.
(3) Indirect examination. In addition to the requirements in
Section 4 of NACE SP0502, the procedures for indirect examination of
the ECDA regions must include--
* * * * *
(4) Direct examination. In addition to the requirements in Section
5 of NACE SP0502, the procedures for direct examination of indications
from the indirect examination must include--
* * * * *
(ii) Criteria for deciding what action should be taken if either:
(A) Corrosion defects are discovered that exceed allowable limits
(Section 5.5.2.2 of NACE SP0502 provides guidance for criteria); or
(B) Root cause analysis reveals conditions for which ECDA is not
suitable (Section 5.6.2 of NACE SP0502 provides guidance for criteria);
* * * * *
(iv) Criteria that describe how and on what basis you will
reclassify and re-prioritize any of the provisions specified in Section
5.9 of NACE SP0502.
(5) Post assessment and continuing evaluation. In addition to the
requirements in Section 6 of NACE SP 0502, the procedures for post
assessment of the effectiveness of the ECDA process must include--
* * * * *
(ii) Criteria for evaluating whether conditions discovered by
direct examination of indications in each ECDA region indicate a need
for reassessment of the pipeline segment at an interval less than that
specified in Sections 6.2 and 6.3 of NACE SP0502 (see appendix D of
NACE SP0502).
29. In Appendix C to Part 195, paragraph (I)(A) introductory text
is revised to read as follows:
Appendix C to Part 195--Guidance for Implementation of an Integrity
Management Program
* * * * *
I. * * *
A. The rule defines a High Consequence Area as a high population
area, an other populated area, an unusually sensitive area, or a
commercially navigable waterway. The Office of Pipeline Safety (OPS)
will map these areas on the National Pipeline Mapping System (NPMS).
An operator, or government official may access the data from the
NPMS home page http:// www.npms.phmsa.dot.gov/. OPS maintains the
NPMS and may update it periodically. However, it is an operator's
responsibility to ensure that it has identified all high consequence
areas that could be affected by a pipeline segment. An operator is
also responsible for periodically evaluating its pipeline segments
to look for population or environmental changes that may have
occurred around the pipeline and to keep its program current with
this information. (Refer to Sec. 195.452(d)(3)).
* * * * *
Issued in Washington, DC, on July 16, 2009.
Jeffrey D. Wiese,
Associate Administrator for Pipeline Safety.
[FR Doc. E9-17307 Filed 7-21-09; 8:45 am]
BILLING CODE 4910-60-P