168 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

FEDERAL COMMUNICATIONS 

COMMISSION 

47 CFR Part 73 

[MB Docket No. 14–159, RM–11735; DA 14– 

1885] 

Television Broadcasting Services; 

Dayton, Ohio 

AGENCY: Federal Communications 

Commission. 

ACTION: Final rule. 

SUMMARY: A petition for rulemaking was 

filed by WKEF Licensee, L.P. (‘‘WKEF 

Licensee’’), the licensee of WKEF(TV), 

channel 51, Dayton, Ohio, requesting 

the substitution of channel 18 for 

channel 51 at Dayton. WKEF Licensee 

filed comments reaffirming its interest 

in the proposed channel substitution 

and explained that the channel 

substitution will eliminate any potential 

interference with wireless operations in 

the Lower 700 MHZ A Block located 

adjacent to channel 51 in Dayton. WKEF 

Licensee further states that it will 

promptly file an application for a 

construction permit for channel 18 and 

place the station into operation. 

DATES: Effective January 5, 2015. 

FOR FURTHER INFORMATION CONTACT: 

Joyce Bernstein, Joyce.Bernstein@

fcc.gov, Media Bureau, (202) 418–1647. 

SUPPLEMENTARY INFORMATION: This is a 

synopsis of the Commission’s Report 

and Order, MB Docket No. 14–159, 

adopted December 23, 2014, and 

released December 23, 2014. The full 

text of this document is available for 

public inspection and copying during 

normal business hours in the FCC’s 

Reference Information Center at Portals 

II, CY–A257, 445 12th Street SW., 

Washington, DC 20554. This document 

will also be available via ECFS (http:// 

fjallfoss.fcc.gov/ecfs/). This document 

may be purchased from the 

Commission’s duplicating contractor, 

Best Copy and Printing, Inc., 445 12th 

Street SW., Room CY–B402, 

Washington, DC 20554, telephone 1– 

800–478–3160 or via the company’s 

Web site, http://www.bcpiweb.com. To 

request materials in accessible formats 

for people with disabilities (braille, 

large print, electronic files, audio 

format), send an email to fcc504@fcc.gov 

or call the Consumer & Governmental 

Affairs Bureau at 202–418–0530 (voice), 

202–418–0432 (tty). 

This document does not contain 

information collection requirements 

subject to the Paperwork Reduction Act 

of 1995, Public Law 104–13. In addition, 

therefore, it does not contain any 

information collection burden ‘‘for 

small business concerns with fewer than 

25 employees,’’ pursuant to the Small 

Business Paperwork Relief Act of 2002, 

Public Law 107–198, see 44 U.S.C. 

3506(c)(4). Provisions of the Regulatory 

Flexibility Act of 1980 do not apply to 

this proceeding. 

The Commission will send a copy of 

the Report and Order in a report to be 

sent to Congress and the Government 

Accountability Office pursuant to the 

Congressional review Act, see 5 U.S.C. 

801(a)(1)(A). 

List of Subjects in 47 CFR Part 73 

Television. 

Federal Communications Commission. 

Hossein Hashemzadeh, 

Deputy Chief, Video Division, Media Bureau. 

For the reasons discussed in the 

preamble, the Federal Communications 

Commission amends 47 CFR part 73 as 

follows: 

PART 73—RADIO BROADCAST 

SERVICES 

■ 1. The authority citation for part 73 

continues to read as follows: 

Authority: 47 U.S.C. 154, 303, 334, 336, 

and 339. 

§ 73.622 [Amended] 

■ 2. Section 73.622(i), the PostTransition Table of DTV Allotments 

under Ohio is amended by removing 

channel 51 and adding channel 18 at 

Dayton. 

[FR Doc. 2014–30863 Filed 1–2–15; 8:45 am] 

BILLING CODE 6712–01–P 

DEPARTMENT OF TRANSPORTATION 

Pipeline and Hazardous Materials 

Safety Administration 

49 CFR Parts 192, 193, 195, 198, and 

199 

[Docket No. PHMSA–2011–0337; Amdt. Nos. 

192–119; 193–25; 195–99; 198–6; 199–26] 

RIN 2137–AE85 

Pipeline Safety: Periodic Updates of 

Regulatory References to Technical 

Standards and Miscellaneous 

Amendments 

AGENCY: Pipeline and Hazardous 

Materials Safety Administration 

(PHMSA), Department of Transportation 

(DOT). 

ACTION: Final rule. 

SUMMARY: PHMSA is amending the 

Federal pipeline safety regulations to 

incorporate by reference new, updated 

or reaffirmed editions of the voluntary 

consensus standards that are applicable 

to pipelines subject to the requirements 

of the Federal pipeline safety 

regulations. This final rule also makes 

non-substantive editorial corrections 

clarifying regulatory language in certain 

provisions. These changes are minor 

and do not require pipeline operators to 

undertake any significant new pipeline 

safety initiatives. 

DATES: This final rule is effective March 

6, 2015. The incorporation by reference 

of certain publications listed in this 

final rule is approved by the Director of 

the Federal Register as of March 6, 2015. 

FOR FURTHER INFORMATION CONTACT: 

Technical Information: Mike Israni by 

phone at 202–366–4571 or by email at 

mike.israni@dot.gov. 

Regulatory Information: Cheryl 

Whetsel by phone at 202–366–4431 or 

by email at cheryl.whetsel@dot.gov. 

SUPPLEMENTARY INFORMATION: 

I. Background 

The National Technology Transfer 

and Advancement Act of 1995 (NTTAA) 

(Pub. L. 104–113; March 7, 1996) directs 

Federal agencies to use voluntary 

consensus standards and design 

specifications developed by voluntary 

consensus standard bodies instead of 

government-developed voluntary 

technical standards when appropriate. 

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 policy for Federal 

use and development of voluntary 

consensus standards. As defined in 

OMB Circular A–119, voluntary 

consensus standards are technical 

standards developed or adopted by 

domestic and international 

organizations. These organizations use 

agreed-upon procedures to update and 

revise their published standards every 

three to five years to reflect modern 

technology and best technical practices. 

The legal effect of incorporation by 

reference (IBR) is that the incorporated 

material is treated as if it were 

published in full in the Federal Register 

and the Code of Federal Regulations 

(CFR). This material, like any other 

properly issued rule, has the force and 

effect of law. Congress authorized 

incorporation by reference to reduce the 

volume of material published in the 

Federal Register and the CFR (see 5 

U.S.C. 552(a) and 1 CFR part 51). 

Congress granted authority to the 

Director of the Federal Register to 

determine whether a proposed IBR 

serves the public interest. Unless 

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Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 169 

expressly provided otherwise in a 

regulation, if a provision of a standard 

incorporated by reference conflicts with 

a regulation, the regulation takes 

precedence. 

New or updated standards often 

further innovation and increase the use 

of new technologies, materials and 

management practices that improve the 

safety and operations of pipelines and 

pipeline facilities. Because pipeline 

safety regulation involves a great deal of 

technical subject matter, there are 64 

standards and specifications that have 

long been incorporated by reference in 

49 CFR part 192, Transportation of 

Natural and Other Gas by Pipeline: 

Minimum Federal Safety Standards; 49 

CFR part 193, Liquefied Natural Gas 

Facilities: Federal Safety Standards; and 

49 CFR part 195, Transportation of 

Hazardous Liquids by Pipeline. PHMSA 

regularly reviews updates to currently 

referenced consensus standards as well 

as new editions of standards to ensure 

that their content remains consistent 

with the intent of the pipeline safety 

regulations. Previous updates to 

incorporate industry standards by 

reference were published on August 11, 

2010 (75 FR 48593), February 1, 2007 

(72 FR 4657), June 9, 2006 (71 FR 

33402), June 14, 2004 (69 FR 32886), 

February 17, 1998 (63 FR 7721), June 6, 

1996 (61 FR 2877), and May 24, 1996 

(61 FR 26121). The list of publications 

that PHMSA has incorporated by 

reference is found in 49 CFR 192.7, 

193.2013, and 195.3. 

PHMSA employees participate in 

more than 25 national voluntary 

consensus standards-setting 

organizations that address pipeline 

design, construction, maintenance, 

inspection and repair. Agency 

participation in the development of 

voluntary consensus standards is 

important to eliminate the necessity for 

development or maintenance of 

separate, government-unique standards, 

to further national goals and objectives 

such as increased use of 

environmentally sound and energyefficient materials, products, systems, 

services or practices and to improve 

public safety. As representatives of the 

agency, these subject matter experts 

actively participate in discussions and 

technical debates, register opinions and 

vote in accordance with the procedures 

of the standards body at each stage of 

the standards development process 

(unless prohibited from doing so by 

law). However, it is important to note 

that agency participation does not 

necessarily constitute agency agreement 

with, or endorsement of, all decisions 

reached by such organizations. PHMSA 

has the responsibility to establish 

regulations and standards that ensure 

pipelines are operated safely and will 

only adopt those portions of industry 

standards into the Federal regulations 

that meet the agency’s goals and best 

promote public safety. 

Availability of Materials to Interested 

Parties 

PHMSA has worked to make the 

materials to be incorporated by 

reference reasonably available to 

interested parties. Section 24 of the 

‘‘Pipeline Safety, Regulatory Certainty, 

and Job Creation Act of 2011’’ (Pub. 

L.112–90, January 3, 2012), amended 49 

U.S.C. 60102 by adding a new public 

availability requirement for documents 

incorporated by reference after January 

3, 2013. The law states: ‘‘Beginning 1 

year after the date of enactment of this 

subsection, the Secretary may not issue 

guidance or a regulation pursuant to this 

chapter that incorporates by reference 

any documents or portions thereof 

unless the documents or portions 

thereof are made available to the public, 

free of charge, on an Internet Web site.’’ 

This section was further amended on 

August 9, 2013. The current law 

continues to prohibit the Secretary from 

issuing a regulation that incorporates by 

reference any document unless that 

document is available to the public, free 

of charge, but removes the Internet Web 

site requirements (Pub. L. 113–30, 

August 9, 2013). The Department of 

Transportation has until August 9, 2015, 

to comply with this provision. 

Pursuant to this mandate, PHMSA has 

negotiated agreements with all but two 

of the standards-setting organizations 

with standards already incorporated by 

reference in the pipeline safety 

regulations to make viewable copies of 

those standards available to the public 

at no cost. The organizations having 

agreements are: American Petroleum 

Institute (API), American Gas 

Association (AGA), American Society 

for Testing and Materials (ASTM), Gas 

Technology Institute (GTI), 

Manufacturers Standardization Society 

of the Valve and Fittings Industry, Inc. 

(MSS), NACE International (NACE), and 

National Fire Protection Association 

(NFPA). Each organization’s mailing 

address and Web site is listed in Parts 

192, 193, and 195. PHMSA understands 

that the two standards organizations 

that we do not have agreements with are 

considering taking steps in addition to 

sales of the standards to achieve greater 

availability. 

II. Summary Review of Standards and 

Amendments 

On August 16, 2013, PHMSA 

published a notice of proposed 

rulemaking (NPRM) to incorporate into 

the pipeline safety regulations two new 

standards: API RP 5LT ‘‘Recommended 

Practice for Truck Transportation of 

Line Pipe’’ (First edition March 1, 2012); 

and ASTM D2513–09a,‘‘Standard 

Specification for Polyethylene (PE) Gas 

Pressure Pipe, Tubing, and Fittings’’ 

(December 1, 2009 (except section 4.2 

pertaining to rework materials) and 21 

updated editions of standards currently 

incorporated by reference. These 

standards affect gas pipelines, liquefied 

natural gas facilities and hazardous 

liquid pipelines (Parts 192, 193, and 

195, respectively). The vast majority of 

the updated standard editions involve 

incremental changes in design, 

maintenance and operation provisions 

as additional knowledge is gained by 

stakeholders. With certain exceptions 

(API RP 1162, ‘‘Public Awareness 

Programs for Pipeline Operators’’ (1st 

edition, December 2003) discussed 

below, PHMSA believes that these 

updates are consistent with the Federal 

pipeline safety mission. In addition, the 

adoption of API RP 5LT addresses 

National Transportation Safety Board’s 

(NTSB) Recommendation P–04–03. 

A. Standards Incorporated 

This final rule accepts the following 

updated editions of technical standards 

currently incorporated by reference in 

Parts 192, 193, and 195: 

American Petroleum Institute 

(1) API Recommended Practice 5L1, 

‘‘Recommended Practice for Railroad 

Transportation of Line Pipe’’ (7th 

edition, September 2009), into 49 CFR 

192.7, 192.65(a)(1), 195.3, 195.207(a). 

[Replaces IBR: API Recommended 

Practice 5L1, ‘‘Recommended Practice 

for Railroad Transportation of Line 

Pipe’’ (6th edition, 2002).] 

(2) API Recommended Practice 5LT, 

‘‘Recommended Practice for Truck 

Transportation of Line Pipe’’ (First 

edition March 1, 2012), into 49 CFR 

192.7, 192.65(c), 195.3, 195.207(c). 

(3) API Recommended Practice 5LW, 

‘‘Transportation of Line Pipe on Barges 

and Marine Vessels’’ (3rd edition, 

September 2009), into 49 CFR 192.7, 

192.65(b), 195.3, 195.207(b). 

[Replaces IBR: API Recommended 

Practice 5LW, ‘‘Transportation of Line 

Pipe on Barges and Marine Vessels’’ 

(2nd edition, December 1996, effective 

March 1, 1997).] 

(4) ANSI/API Specification 5L, 

‘‘Specification for Line Pipe’’ (45th 

edition, December 1, 2012, effective July 

1, 2013), into 49 CFR 192.7; 192.55(e); 

192.112(a)(4); 192.112(b)(1)(i); 

192.112(b)(1)(iii); 192.112(b)(2)(iv); 

192.112(d)(1); 192.112(e)(1); 192.113; 

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170 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

Item I, Appendix B to Part 192; 195.3; 

195.106(b)(1)(i); 195.106(e). 

[Replaces IBR: ANSI/API 

Specification 5L/ISO 3183, 

‘‘Specification for Line Pipe’’ (44th 

edition, 2007), includes errata (January 

2009) and addendum (February 2009).] 

(5) ANSI/API Specification 6D, 

‘‘Specification for Pipeline Valves’’ 

(23rd edition, April 1, 2008, effective 

October 1, 2008), includes Errata 1 (June 

2008), Errata 2 (November 2008), Errata 

3 (February 2009), Errata 4 (April 2010), 

Errata 5 (November 2010), Errata 6 

(August 2011), Addendum 1 (October 

2009), Addendum 2 (August 2011), and 

Addendum 3 (October 2012) into 49 

CFR 192.7; 192.145(a); 195.3, 

195.116(d). 

[Replaces IBR: ANSI/API 

Specification 6D, ‘‘Specification for 

Pipeline Valves’’ (23rd edition (April 

2008, effective October 1, 2008)) and 

Errata 3 (includes 1 and 2, February 

2009).] 

(6) API Specification 12F, 

‘‘Specification for Shop Welded Tanks 

for Storage of Production Liquids’’ (12th 

edition, October 2008, effective April 1, 

2009) into 49 CFR 195.3, 195.132(b)(1), 

195.205(b)(2), 195.264(b)(1), 

195.264(e)(1), 195.307(a), 195.565, 

195.579(d). 

[Replaces IBR: API Specification 12F, 

‘‘Specification for Shop Welded Tanks 

for Storage of Production Liquids,’’ 

(11th edition, November 1, 1994, 

reaffirmed 2000, errata, February 2007);] 

(7) API Standard 620, ‘‘Design and 

Construction of Large, Welded, Lowpressure Storage Tanks’’ (11th edition, 

February 2008), addendum 1, (March 

2009), addendum 2 (August 2010), and 

addendum 3 (March 2012) into 49 CFR 

193.2013; 193.2101(b); 193.2321(b)(2); 

195.3; 195.132(b)(2); 195.205(b)(2); 

195.264(b)(1); 195.264(e)(3); 195.307(b); 

195.565; 195.579(d). 

[Replaces IBR: API Standard 620, 

‘‘Design and Construction of Large, 

Welded, Low-Pressure Storage Tanks’’ 

(11th edition, February 2008, addendum 

1 March 2009).] 

(8) API Standard 650, ‘‘Welded Tanks 

for Oil Storage’’ (11th edition, June 

2007, effective February 1, 2012), 

includes addendum 1 (November 2008), 

addendum 2 (November 2009), 

addendum 3 (August 2011), and errata 

(October 2011) into 49 CFR 195.3; 

195.132(b)(3); 195.205(b)(1); 

195.264(b)(1); 195.264(e)(2); 195.307(c); 

195.307(d); 195.565; 195.579(d). 

[Replaces IBR: API Standard 650, 

‘‘Welded Steel Tanks for Oil Storage’’ 

(11th edition, June 2007), addendum 1 

(November 2008).] 

(9) ANSI/API Standard 2000, 

‘‘Venting Atmospheric and Lowpressure Storage Tanks’’ (6th edition, 

November 2009) into 49 CFR 195.3, 

195.264(e)(2), 195.264(e)(3). 

[Replaces IBR: API Standard 2000, 

‘‘Venting Atmospheric and LowPressure Storage Tanks NonRefrigerated and Refrigerated’’ (5th 

edition, April 1998, errata, November 

1999).] 

American Society for Testing and 

Materials (ASTM) 

(1) ASTM A53/A53M–10, ‘‘Standard 

Specification for Pipe, Steel, Black and 

Hot-Dipped, Zinc-Coated, Welded and 

Seamless’’ (October 1, 2010), into 49 

CFR 192.7; 192.113; Item 1, Appendix B 

to Part 192; 195.3; 195.106(e). 

[Replaces IBR: ASTM A53/A53M–07, 

‘‘Standard Specification for Pipe, Steel, 

Black and Hot-Dipped, Zinc-Coated 

Welded and Seamless’’ (September 1, 

2007).] 

(2) ASTM A106/A106M–10, 

‘‘Standard Specification for Seamless 

Carbon Steel Pipe for High-Temperature 

Service’’ (October 1, 2010), into 49 CFR 

192.7; 192.113; Item 1, Appendix B to 

Part 192; 195.3; 195.106(e). 

[Replaces IBR: ASTM A106/A106M– 

08, ‘‘Standard Specification for 

Seamless Carbon Steel Pipe for HighTemperature Service’’ (July 15, 2008).] 

(3) ASTM A333/A333M–11, 

‘‘Standard Specification for Seamless 

and Welded Steel Pipe for LowTemperature Service’’ (April 1, 2011), 

into 49 CFR 192.7; 192.113; Item 1, 

Appendix B to Part 192; 195.3; 

195.106(e). 

[Replaces IBR: ASTM A333/A333M– 

05, ‘‘Standard Specification for 

Seamless and Welded Steel Pipe for 

Low-Temperature Service’’ (March 1, 

2005).] 

(4) ASTM A372/A372M–10, 

‘‘Standard Specification for Carbon and 

Alloy Steel Forgings for Thin-Walled 

Pressure Vessels’’ (October 1, 2010), into 

49 CFR 192.7, 192.177(b)(1). 

[Replaces IBR: ASTM A372/A372M– 

03 (reapproved), ‘‘Standard 

Specification for Carbon and Alloy Steel 

Forgings for Thin-Walled Pressure 

Vessels’’ (March 1, 2008).] 

(5) ASTM A671/A671M–10, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for 

Atmospheric and Lower Temperatures’’ 

(April 1, 2010), into 49 CFR 192.7; 

192.113; Item 1, Appendix B to Part 192; 

195.3; 195.106(e). 

[Replaces IBR: ASTM A671–06 (2006) 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for 

Atmospheric and Lower Temperatures’’ 

(May 1, 2006).] 

(6) ASTM A672/A672M–09, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for HighPressure Service at Moderate 

Temperatures’’ (October 1, 2009), into 

49 CFR 192.7; 192.113; Item 1, 

Appendix B to Part 192; 195.3; 

195.106(e). 

[Replaces IBR: ASTM A672–08, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for HighPressure Service at Moderate 

Temperatures’’ (May 1, 2008).] 

(7) ASTM A691/A691M–09, 

‘‘Standard Specification for Carbon and 

Alloy Steel Pipe, Electric-FusionWelded for High-Pressure Service at 

High Temperatures’’ (October 1, 2009), 

into 49 CFR 192.7; 192.113; Item 1, 

Appendix B to Part 192; 195.3; 

195.106(e). 

[Replaces IBR: ASTM A691–98 

(reapproved 2007), ‘‘Standard 

Specification for Carbon and Alloy Steel 

Pipe, Electric-Fusion-Welded for HighPressure Service at High Temperatures’’ 

(November 1, 2007).] 

(8) ASTM D2513–09a, ‘‘Standard 

Specification for Polyethylene (PE) Gas 

Pressure Pipe, Tubing, and Fittings’’ 

(December 1, 2009), into 49 CFR 192.7; 

192.123(e); 192.191(b); 192.283(a); Item 

1, Appendix B to Part 192. 

Manufacturers Standardization Society 

of the Valve and Fittings Industry, Inc. 

(MSS) 

(1) MSS SP–44–2010, Standard 

Practice, ‘‘Steel Pipeline Flanges’’ (2010 

edition, includes Errata, May 20, 2011), 

into 49 CFR 192.7, 192.147(a). [Replaces 

IBR: MSS SP–44–2006, Standard 

Practice, ‘‘Steel Pipeline Flanges’’ (2006 

edition).] 

(2) MSS SP–75–2008, Standard 

Practice, ‘‘Specification for High-Test, 

Wrought Butt-Welding Fittings’’ (2009 

edition), into 49 CFR 195.3, 195.118(a). 

[Replaces IBR: MSS SP–75–2004, 

‘‘Specification for High Test Wrought 

Butt Welding Fittings’’ (2004 edition).] 

NACE International (NACE) 

(1) ANSI/NACE Standard SP0502– 

2010, Standard Practice, ‘‘Pipeline 

External Corrosion Direct Assessment 

Methodology’’ (June 24, 2010), into 49 

CFR 192.7; 192.923(b)(1); 192.925(b), 

(b)(1), (b)(1)(ii), (b)(2), (b)(3), 

(b)(3)(ii)(A), (b)(3)(ii)(B), (b)(3)(iv), 

(b)(4), (b)(4)(ii); 192.931(d); 

192.935(b)(1)(iv); 192.939(a)(2); 195.3; 

195.588(b)(1), (b)(2), (b)(2)(iii), (b)(3), 

(b)(4), (b)(4)(ii)(A), (b)(4)(ii)(B), (b)(iv), 

(b)(5), (b)(5)(ii). 

[Replaces IBR: NACE SP0502–2008, 

Standard Practice, ‘‘Pipeline External 

Corrosion Direct Assessment 

Methodology’’ (reaffirmed March 20, 

2008).] 

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Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 171 

National Fire Protection Association 

(NFPA) 

(1) NFPA–30 (2012), ‘‘Flammable and 

Combustible Liquids Code,’’ includes 

Errata 1, Errata 2 (2012 edition, June 20, 

2011), into 49 CFR 192.7, 192.735(b), 

195.3, 195.264(b)(1). 

[Replaces IBR: NFPA–30, ‘‘Flammable 

and Combustible Liquids Code’’ (2008 

edition, approved August 15, 2007).] 

(2) NFPA–70 (2011), ‘‘National 

Electrical Code’’ (2011 edition, 

approved August 5, 2010), into 49 CFR 

192.7, 192.163(e), 192.189(c). [Replaces 

IBR: NFPA 70 (2008), ‘‘National 

Electrical Code’’ (NEC 2008, approved 

August 15, 2007).] 

B. Standards Not Incorporated 

PHMSA did not propose to 

incorporate by reference API 

Recommended Practice (RP) 1162 

(second edition, December 2010); API 

Standard (Std) 653 (4th edition) and 

Addendum (2010); or section 4.2, 

‘‘Rework Material’’ of ASTM D2513– 

09a, ‘‘Standard Specification for 

Polyethylene (PE) Gas Pressure Pipe, 

Tubing, and Fittings.’’ except for 

PHMSA has not incorporated these 

three standards because: 

• API RP1162–2003—This rule 

retains API RP 1162, ‘‘Public Awareness 

Programs for Pipeline Operators’’ (1st 

edition, December 2003). PHMSA has 

decided not to incorporate the second 

edition at this time because it intends to 

consult with state pipeline authorities 

after they report on the results of their 

2012 state compliance inspections. 

These inspections were based on the 

criteria in the first edition. A public 

workshop will then be conducted to 

discuss the inspection data and best 

practices. 

• API Std 653–2001—This rule 

retains API Std 653–2001, ‘‘Tank 

Inspection, Repair, Alteration, and 

Reconstruction’’ (3rd edition, December 

2001), with the exception of section 

6.4.3, ‘‘Alternative Internal Inspection 

Interval.’’ PHMSA has decided to 

exclude section 6.4.3 because of 

concerns that the risk-based inspection 

(RBI) procedures described in section 

6.4.3 of the standard do not require 

adequate or consistent assessment 

factors for establishing an alternate 

internal inspection interval. First, the 

standard states that an operator 

‘‘should’’ consider certain factors in 

making an RBI assessment of a tank, but 

it does not make such consideration 

mandatory. Second, the RBI procedures 

described in section 6.4.3 would allow 

operators to establish minimum bottom 

plate thicknesses less than the 

minimum values referenced in table 6– 

1, ‘‘Bottom Plate Minimum Thickness,’’ 

and section 4.4.5.4, ‘‘Minimum 

Thickness for Tank Bottom Plate.’’ 

Third, the procedures may also increase 

or decrease the 20-year inspection 

interval described in 6.4.2.1, ‘‘Internal 

Intervals.’’ PHMSA does not agree with 

allowing such a lengthy interval 

between inspections. 

Under this rule, any operator who 

previously established an alternate 

internal inspection interval using the 

procedures in section 6.4.3 must 

reestablish such intervals based on 

section 6.4.2, ‘‘Inspection Intervals,’’ of 

API Std 653–2001 within 2 years from 

the date of this final rule. 

• ASTM D2513–09a—PHMSA will 

incorporate ASTM D2513–09a, 

‘‘Standard Specification for 

Polyethylene (PE) Gas Pressure Pipe, 

Tubing, and Fittings,’’ except section 

4.2, ‘‘Rework Material.’’ Section 4.2 

states: ‘‘Clean rework material of the 

same commercial designation, generated 

from the manufacturer’s own pipe and 

fitting production shall not be used 

unless the pipe and fitting produced 

meets all the requirements of this 

specification. The use of these rework 

materials shall be governed by the 

requirements of section 4.3 and Plastic 

Pipe Institute (PPI) Technical Note TN– 

30/2006.’’ 

Currently, rework materials are 

limited to a maximum of 30 percent by 

weight. One of the main steps of plastic 

pipe manufacturing includes an 

extrusion process, where raw or virgin 

material (usually supplied in the form of 

pellets) is heated, melted, mixed and 

conveyed into a die and shaped into a 

pipe. Rework (also known as regrind) is 

a process by which plastic pipe that 

does not fall within acceptable 

specifications following the extrusion 

process can be reused if it meets the 

requirements of Section 4.2, including 

requirements in PPI TN–30/2006. 

Requirements in PPI TN–30/2006 

include reducing the size of the material 

through appropriate stages (i.e. 

regrinding the material) to an equivalent 

size to the raw virgin pellet material and 

avoiding contamination. The ground up 

material is then mixed back in with a 

portion of raw pellet material prior to 

going back through the extrusion 

process. Despite these requirements, 

PHMSA believes prohibiting the use of 

rework material is the only way to 

ensure the materials used by operators 

are not contaminated during the 

manufacturing process. This topic 

received a number of comments and 

was discussed in detail at the advisory 

committee meetings. Information about 

these comments is provided in Section 

IV. 

During the drafting process of this 

final rule, the Federal Register advised 

that PHMSA would not be allowed to 

include an exception clause to the list 

of standards in the centralized listing as 

PHMSA had discussed in the NPRM 

and at the advisory committee meeting. 

Instead, revisions are noted in each of 

the affected sections to accommodate 

the incorporation of ASTM D2513–09a 

for PE pipe and the continued 

incorporation of ASTM D2513–87 and 

ASTM D2513–99 for non-PE plastic 

pipe. The revisions are summarized 

below: 

Æ In § 192.7, PHMSA is adding ASTM 

D2513–09a to the listing of documents 

incorporated by reference. 

Æ In § 192.59, PHMSA is adding a 

new paragraph (d) to specify that 

PHMSA will prohibit rework for all 

plastic pipe manufactured after the 

effective date of this final rule and used 

in pipeline systems subject to Part 192. 

Æ In § 192.63(a)(1), PHMSA is 

clarifying that ASTM D2513–87 applies 

to plastic pipe and fittings made of 

materials other than polyethylene. 

Æ In § 192.123(e)(2), PHMSA is 

including verbiage to indicate that 

ASTM D2513–09a pertains to PE pipe 

only. 

Æ In § 192.191, PHMSA is clarifying 

that ASTM D2513–99 is applicable to 

plastic materials other than 

polyethylene and is adding a reference 

to ASTM D2513–09a applicable to PE 

materials only. 

Æ In § 192.283(a)(1)(i), PHMSA is 

clarifying that ASTM D2513–99 is 

applicable to plastic materials other 

than polyethylene and is adding a 

reference to ASTM D2513–09a 

applicable to polyethylene plastic (PE) 

materials only. 

Æ In Part 192, Appendix B, Section 1, 

PHMSA is adding ASTM D2513–09a to 

the list of pipe specifications. 

C. Editorial Corrections and 

Clarifications 

This final rule is also making several 

non-substantive editorial amendments 

to Parts 192, 193, and 195, and 198. The 

final rule: 

• Changes the ‘‘Centralized IBR 

Sections’’ from a table format to a 

listing. 

• Adds abbreviated titles to the list of 

standards to be incorporated in §§ 192.7, 

193.2013, and 195.3. 

• Revises current titles to abbreviated 

titles. 

• Corrects the reference to the Gas 

Technology Institute (GTI) research 

document (formerly the Gas Research 

Institute (GRI)) document number from 

GRI–89/0242 to GTI–04/0049. 

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• Removes an incorrect reference to 

ASME Boiler & Pressure Code, Section 

VII, Division 2 in § 193.2321. 

• Inserts the year of certain standards 

where more than one edition may be 

applied. 

• Inserts the notation ‘‘Incorporated 

by Reference’’ in the regulation text if 

not included previously. 

In addition, the following technical 

corrections and changes are being made 

to specific sections as follows: 

• Section 192.283(a)(1)(i) currently 

states ‘‘or par. 8.9 (Sustained Static 

Pressure Test)’’. This sentence has been 

deleted because PHMSA believes the 

reference is an error. Paragraph 8.9 does 

not exist in current edition of ASTM 

D2513–99 nor does it appear in several 

other versions of this referenced 

standard. PHMSA’s staff researched 

several editions of ASTM D2513, the 

pipeline safety regulations and Federal 

Register notices to determine if the 

paragraph may have been associated 

with a different standard but found no 

reference to paragraph 8.9. Furthermore, 

PHMSA is clarifying that ASTM D2513– 

09a is for PE pipe only as this section 

pertains to both PE manufactured to 

ASTM D2513–09a and non-PE plastic 

manufactured to ASTM D2513–99. The 

resulting language will read, ‘‘In the 

case of thermoplastic pipe, paragraph 

6.6 (Sustained Pressure Test) or 

paragraph 6.7 (Minimum Hydrostatic 

Burst Test) of ASTM D2513–99 for 

plastic materials other than 

polyethylene or ASTM D2513–09a for 

polyethylene plastic materials 

(incorporated by reference, see 

§ 192.7).’’ 

• Section 195.264(b)(1)(i) and (ii) 

reference section numbers from an 

earlier edition of NFPA–30 previously 

incorporated by reference. The section 

references are changed to reflect the 

current edition section numbers from 

NFPA–30 (2012). The new section 

numbers are 22.11.1 and 22.11.2. 

• Section 195.432(b) states that 

operators must inspect the physical 

integrity of in-service atmospheric and 

low pressure steel aboveground 

breakout tanks in accordance with API 

Standard 653. PHMSA is amending this 

section by disallowing the use of the 

procedures in section 6.4.3, Alternative 

Internal Inspection Interval, of API 

Standard 653. This final rule also 

provides instruction to operators who 

previously calculated alternative 

internal inspection intervals using the 

guidance in section 6.4.3 of API Std 653. 

• Section 195.452(l) states that an 

operator must maintain certain records 

for review during an integrity 

management (IM) inspection. In this 

rule, PHMSA is establishing that 

operators must maintain their IM 

records for the useful life of the pipe. 

• Section 198.37(f) states operators of 

underground pipeline facilities 

participating in one-call facility 

notification systems must be required to 

respond in the manner prescribed in 

§ 192.614(b)(4) through (b)(6). This 

section is changed to reflect the correct 

references from § 192.614(b)(4) through 

(b)(6) to § 192.614(c)(4) through (c)(6). 

• Section 199.111 contains 

conflicting requirements as those stated 

in 49 CFR part 40 causing confusion for 

both the covered employee and the 

operator who must comply with this 

section and with Part 40. For example, 

in Part 40, it is the responsibility of the 

medical review officer (MRO) to select 

the laboratory to which the split sample 

should be sent however in § 199.111 the 

specimen donor (i.e., the covered 

employee), and not the MRO, selects the 

testing laboratory to which his/her split 

specimen should be sent for 

corroborating evaluation. Another 

discrepancy between the regulations 

deals with whether the same laboratory 

can retest a split specimen. In order to 

eliminate these conflicts, PHMSA is 

removing section § 199.111. Operators 

are to follow the requirements in Part 

40. 

III. Advisory Committees Actions 

On December 17, 2013, and February 

25, 2014, PHMSA conducted meetings 

of the Technical Pipeline Safety 

Standards Committee (TPSSC) and the 

Technical Hazardous Liquid Pipeline 

Safety Standards Committee (THLPSSC) 

to discuss the NPRM and its regulatory 

evaluation. These statutorily-mandated 

committees advise PHMSA on the 

technical feasibility, reasonableness, 

and cost-effectiveness of its proposed 

regulations. At the December meeting, 

in accordance with 49 U.S.C. 

60102(b)(2)(G), each of the committees 

voted in favor of adopting all of the 

proposed standards to be incorporated, 

but there were additional comments and 

questions about rework and the impact 

of PHMSA’s proposal to incorporate 

ASTM D2513–09a with the exception of 

section 4.2, ‘‘Rework Material.’’ 

Members were particularly interested in 

learning more about the manufacturing 

process and potential contamination 

during the extrusion process, and in 

soliciting additional information and 

opinions from industry experts. 

On February 25, 2014, the committees 

met again. PHMSA presented more 

information on the topic of rework and 

regrind issues. Additionally, a panel of 

experts, including representatives from 

the National Association of Pipeline 

Safety Representatives (NAPSR), the 

AGA, the PPI, and an independent 

consultant heavily involved with ASTM 

standards development, provided their 

perspectives on the topic. All 

representatives, with the exception of 

the PPI representative, supported the 

PHMSA proposal. The PPI suggested an 

alternative that would limit the use of 

rework to pipe larger than 2 inches in 

diameter. Additional comments from 

the panelists are provided in Section IV 

of this document. 

In February, the TPSSC voted 

unanimously to recommend that the 

NPRM, excluding rework issues, was 

technically feasible, reasonable, 

practicable, and cost-effective. 

Prohibiting rework does not affect the 

liquid industry. 

Transcripts from the committee 

meetings are available in the docket for 

this rulemaking and in the advisory 

committees’ meeting dockets. 

IV. Summary of Comments 

PHMSA received comments from nine 

organizations in response to the NPRM, 

including: MSS; API; NFPA; Pipeline 

Plastics, LLC; Southwest Gas 

Corporation; Chevron Phillips Chemical 

Company; PPI; and AGA. 

At the two advisory committee 

meetings, comments were also received 

from the organizations mentioned 

above, members of the TPSSC and the 

THLPSSC and from representatives of 

the Virginia State Corporation 

Commission and NAPSR. Their 

comments are summarized below. 

A. Miscellaneous Changes 

MSS recommended that PHMSA 

incorporate by reference the 2011 errata 

to MSS SP–44–2010, Standard Practice, 

‘‘Steel Pipeline Flanges.’’ PHMSA agrees 

with this comment and will include the 

errata, which contains a minor 

correction to Table C4 of the standard 

that corrects the number of bolt holes 

from 28 to 32 for 42-inch-diameter pipe. 

The NFPA representative and a 

PHMSA staff member noted that in 

existing § 195.264(b)(1)(i) and (ii), the 

section references to the standard 

incorporated by reference, (i.e., NFPA– 

30 (2012 edition)), were incorrect. 

Therefore, the section references will 

change from section 4.3.2.3.2 to section 

22.11.1. 

The API provided comments on 

incorporating standards, some of which 

had not been finalized until after the 

NPRM was published, and others that 

were outside the scope of this notice, 

including: API Std 653, API RP 1162, 

API RP 1164, and NFPA–70. 

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1Operations Technology Development (OTD) is a 

not-for-profit corporation led by 22 members who 

serve over 28 million natural gas consumers in 27 

states and Canada. OTD develops advanced 

technologies for the natural gas industry; U.S. 

utilities combined interests, expertise, and 

resources into focused Research & Development 

projects. 

B. Comments and Discussion on Rework 

and Incorporating ASTM D 2513–87, 

–99, –09a, ‘‘Specifications for 

Thermoplastic Gas Pressure Pipe, 

Tubing and Fittings’’ (except section 4.2, 

‘‘Rework Materials) 

• ASTM D2513–87 and –99—The 

Southwest Gas Corporation 

recommended that PHMSA eliminate 

the incorporation by reference of ASTM 

D2513–87, ‘‘Standard Specification for 

Thermoplastic Gas Pressure Pipe, 

Tubing, and Fittings’’ (for nonpolyethylene plastic materials only) in 

§§ 192.7 and 192.63(a)(1) for marking 

only, in favor of incorporating the 1999 

edition of the standard. Southwest 

indicated that the reference to the 1987 

edition was introduced in an earlier 

amendment to the code at the same time 

ASTM D1990c was incorporated as an 

update to the 1987 version. Southwest 

Gas believed the 1990c version did not 

require operators to identify certain 

temperature ratings for fittings, so the 

1987 version was retained. With the 

release of the 1999 edition, the 

temperature-marking requirement for 

fittings was restored, so Southwest Gas 

believed it would be a more appropriate 

version to use for marking as well. 

PHMSA staff recalled that the 1990c 

edition did not require fittings that were 

intended for use at elevated 

temperatures to be marked to identify 

certain temperature ratings, a 

requirement that PHMSA believed was 

beneficial. Therefore, the 1987 edition 

continued to be referenced for the 

purpose of marking thermoplastic 

fittings. With the release of the 1999 

edition, however, the marking intervals 

were increased from 2 feet to 5 feet. 

PHMSA has decided to retain the 1987 

version of ASTM D2513 for purposes of 

marking of non-polyethylene plastic 

materials because it requires operators 

to mark pipe and tubing at intervals of 

not more than 2 feet. PHMSA prefers 

this more stringent requirement because 

the less spacing there is between 

markings along a pipe, the easier it is to 

identify the pipe during excavation. A 

smaller interval also helps reduce the 

size of the ditch/hole needed for 

excavation. The more stringent 

requirement is also present in the 2009a 

version of ASTM D2513 for 

polyethylene pipe and fittings, so ASTM 

D2513–09a will be IBR for purposes of 

marking PE materials only. 

PHMSA has revised § 192.63(a)(1) to 

clarify that ASTM D2513–87 would 

continue to apply to the marking of nonPE materials. A specific reference to 

ASTM D2513–09a is not needed in 

192.63(a)(1) to address marking for PE 

materials because (1) it is already listed 

in Appendix B to Part 192, and (2) other 

language in § 192.63(a)(1) already 

requires each valve, fitting, length of 

pipe and other component to be marked 

as prescribed in the specification or 

standard to which it was manufactured. 

• ASTM D 2513–09a (except section 

4.2, ‘‘Rework Materials’’)—The 

following entities provided comments 

on the incorporation of ASTM D2513– 

09a and the proposal to exclude the use 

of rework materials: AGA; Pipeline 

Plastics, LLC; PPI and Chevron Phillips 

Chemical Company. All of these 

organizations were in favor of 

incorporating ASTM D2513–09a for PE 

pipe, but had varying comments on the 

exclusion of rework materials. 

The AGA provided comments to the 

docket based on input from its Plastic 

Materials Committee (PMC), which 

includes operators and plastic pipe 

manufacturers. Based on discussions 

within the PMC, the AGA suggested an 

alternative based on pipe diameter, 

whereby no rework material would be 

allowed for pipe 2 inches Iron Pipe Size 

(IPS) and below in diameter and the 

requirements in ASTM D2513–09a, 

section 4.2 would be acceptable for pipe 

larger than 2 inches IPS in diameter. 

The AGA contended that to the extent 

there are material issues with rework, it 

is reasonable to believe that the risks are 

greater with smaller-diameter, thinnerwall pipe, specifically, pipe smaller 

than 2 inches in diameter. According to 

AGA, many operators have used the 2- 

inch diameter as a threshold for 

prohibiting the use of rework, while 

others require virgin plastic for all their 

piping. The AGA suggested that 

establishing the 2-inch diameter 

threshold could be a reasonable step as 

operators and manufacturers continue to 

seek consensus and discuss the issue 

within the PMC and with PHMSA. 

At the February advisory committee 

meetings, a member of the TPSSC and 

a gas operator provided comments on 

behalf of AGA indicating that, while in 

previous comments to the docket, the 

organization had recommended PHMSA 

adopt an alternative that rework only be 

allowed for pipe greater than 2 inches 

in diameter, it now recognized that 

some of its members now believed there 

were continued safety concerns with the 

use of reworked pipe and, in an effort 

to move forward, the AGA supported 

the adoption of ASTM D2513–09a 

without rework. The PPI, a major trade 

association representing all segments of 

the plastics pipe industry, and Pipeline 

Plastics, LLC, a major manufacturer of 

polyethylene pipe, opposed the 

exclusion of rework and recommended 

that ASTM D2513–09a be incorporated 

in its entirety. These two organizations 

referred to the Operations Technology 

Development, NFP 1 (OTD) company’s 

research Project No. 2.ff (summary 

version) titled ‘‘Evaluation for Impact of 

Rework’’ which was referenced in the 

2009 standard and PPI Technical Note 

30 (TN–30), which concluded that the 

proper handling and use of rework does 

not have a negative effect on any of the 

three performance parameters for PE gas 

pipe. Therefore, these organizations 

believe adhering to the 2009 standard 

and PPI TN–30, which provides 

guidance for manufacturers and endusers on the safe and proper use of 

rework, would adequately address 

rework. 

The PPI and Pipeline Plastics, LLC 

also contended there could be 

environmental and cost impacts 

associated with prohibiting rework. 

These organizations stated that if rework 

were prohibited, additional unused 

plastic could be put in landfills. They 

also indicated that the unused plastic 

could be used for other plastic 

processing operations, such as blow 

molding. 

The PPI estimated that using PE scrap 

in blow molding rather than regrind in 

pipe production could potentially 

increase PE pipe manufacturer costs by 

$1 million to $3 million annually. This 

estimate is based on 2013 PPI resin 

usage (est. 200,000,000 lbs. used in gas 

distribution pipe production), current 

market resin pricing data (price 

differential of $0.10 to $0.15 per pound 

between pipe grade and blow mold 

grade resins), and an estimated 5 to 10 

percent scrap generation from extrusion. 

At the February joint advisory 

committee meeting, a manufacturer 

representing PPI raised similar concerns 

to those raised during the comment 

period. The following concerns were 

presented. 

Æ Cost of gas distribution pipe. The 

PPI felt that there is no other market in 

North America for medium-density 

polyethylene pipe other than gas 

distribution, the majority of which uses 

medium density pipe. The PPI stated 

that all other polyethylene markets use 

high-density pipe. Therefore, if 

reworked pipe is not allowed, the cost 

of the medium-density pipe would be 

discounted to a non-pressure pipe or 

commodity product price. This could 

cause manufacturers to see an inherent 

loss in value based on scrap levels. 

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Some manufacturers felt the estimated 

$1 million to $3 million cost impact was 

low because there is no true alternative 

market to sell pipe that can’t be used for 

gas transportation. It would not be 

worth regrinding pipe, transferring that 

material to another facility and 

manufacturing something else. The PPI 

admitted it couldn’t share more detailed 

costs due to anti-trust concerns and, 

therefore, was unable to give a true 

number. 

Æ Eliminating rework won’t result in 

better-quality pipe. PPI expressed the 

view that eliminating rework won’t 

necessarily result in better-quality pipe 

and rework doesn’t address other 

sources of contamination. In the PPI’s 

opinion, rework pressures operators and 

manufacturers to minimize scrap. The 

PPI also felt there was no true way to 

test a pipe later to determine whether or 

not it was manufactured with rework 

material. If operators required no rework 

in their specifications, it would be 

difficult to trace and audit. 

Æ Oil and gas gathering lines. The PPI 

indicated it had several members whose 

pipelines had previously been 

unregulated but which had now became 

regulated due to encroaching 

development. To protect themselves, 

midstream users are requiring pipe for 

oil and gas gathering lines to meet 

ASTM D2513. If rework is not allowed, 

midstream users will also have to 

comply. The industry is concerned if 

reworked pipe is not allowed for oil and 

gas gathering lines, which is almost half 

of the total pressure pipe market, there 

would be an even larger cost impact. 

Based on their concerns, the PPI 

suggested an alternative to only prohibit 

rework in pipes larger than 2 inches in 

diameter. 

Dura-Line, a pipeline manufacture, 

stated that their company has been 

rework-free for a full year and that they 

instead supported the AGA’s position to 

not allow rework. The statement was 

made for the record that its position was 

not unanimous among its membership. 

Another member of the public stated 

that while the vote at the PPI was not 

unanimous, the PPI has a consensus 

process to follow, and it was the 

decision of their Energy Piping Systems 

Committee to move this issue forward in 

the manner they did. This individual 

urged support of the PPI 

recommendation. 

Chevron Phillips preferred 

incorporating ASTM D2513–09a in its 

entirety but suggested if additional 

limitations were to be adopted, it would 

recommend adopting sizing restrictions, 

such as limiting the use of rework to 

pipes with wall thicknesses greater than 

0.170 inches. They also suggested there 

could be additional costs associated 

with prohibiting rework. According to 

Chevron Phillips, PE gas pipe resins are 

specifically tailored through processing 

and additives to yield the highest 

quality pipe and fitting products. If the 

rework materials from these products 

cannot be used in the manufacture of 

gas pipes, they will be less valuable in 

alternate products. According to 

Chevron Phillips, the cost of the raw 

material is by far the largest contributor 

to the overall cost of the pipe or fittings, 

and an increased cost would have to be 

passed on to the utilities and 

consumers, which will affect the 

competitive position of PE gas pipe. 

An independent expert discussed his 

experience with both operators and the 

standards developing committees, and 

the extent to which other countries 

allow rework. He stated that Canada is 

considering not allowing rework in the 

Canadian Standards Association (CSA) 

B137.4, which is the standard similar to 

ASTM D2513 for polyethylene gas pipe. 

He also reported that rework is not 

allowed in France, the Netherlands, 

Belgium and Korea. The United 

Kingdom requires that either no rework 

material be used, or, if it is used, the 

pipe must be 100 percent reworked 

material (not a combination). He also 

acknowledged the ongoing work in 

ASTM to develop a standard for the 

proper use of rework and a recent 

revision to PPI TN–30, both of which he 

acknowledged are good documents. 

However, in his opinion, these 

documents mainly provide good 

recommendations for material handling. 

He believed the only true guaranteed 

means to prevent contamination from 

rework is not to allow rework in ASTM 

D2513–09a. He noted that although he 

is a member of the PPI, he was not in 

support of the group’s position and 

recommended the advisory committees 

support the PHMSA proposal regarding 

adoption of ASTM D2513–09a, with the 

exception of rework. 

An individual from the Virginia State 

Corporation Commission (speaking on 

behalf of himself) stated that he had 

conducted research on the use of rework 

in the U.S. and in other parts of the 

world. He expressed concern that PPI 

TN–30 provides no guidance on 

cleaning, the verification process, or 

testing requirements prior to regrind 

material use, which does not assure that 

reground material is free from 

contamination. He also stated that using 

magnets to attract certain materials is 

not reliable, as magnets do not attract 

particles including non-ferrous 

materials, brass, aluminum and dust. He 

stated that some pipe might also sit for 

periods of time with the manufacturer 

and become oxidized, which causes 

harm to pipe material. Such oxidized 

pipe may then be ground up and 

introduced into the rework process. He 

added that rework is not allowed for 

pipe built to American Association of 

State of Highway Transportation 

Officials’ standards, and that ASTM is 

currently working on a standard, ASTM 

WK–37322, where they are looking to 

the possibility of eliminating the use of 

rework entirely. 

C. Advisory Committees—Action/Q & A 

A member from the Iowa Utilities 

Board asked why some operators require 

virgin plastic materials while others use 

the 2-inch measure as explained by 

AGA. PHMSA explained that the use of 

virgin plastic or the 2-inch measure is 

determined on an operator-by-operator 

basis. A member of the gas committee, 

representing industry, stated that 

National Grid uses only virgin material 

plastic. The selection and use of the 

material is decided by their materials 

engineering manager who bases his 

decision on experience, examination of 

pipe tested in their lab, and field work. 

Ultimately, the materials engineering 

manager was more comfortable with 

using virgin material. 

A member of the liquid committee, 

representing the Virginia State 

Corporation Commission, stated that 

from his experience, companies in 

Virginia recognize that using virgin 

materials may not be the real issue at 

all. Instead, there is more of a concern 

that there is opportunity for pipe 

material to be contaminated during the 

manufacturing process. The plastic pipe 

manufacturing process is an area where 

there are few standards. 

A member of the gas committee, 

representing the public from Hartford 

Steam Boiler, asked how PHMSA would 

control the implementation of a 

standard that banned the use of rework 

but where the pipe was marked as 

meeting specifications and the industry 

specification permitted rework material. 

PHMSA replied that, from a regulatory 

standpoint, the IBR of ASTM D2513– 

09a would have a caveat stating the 

exception to section 4.2 (addressing 

rework). In addition, a documentation 

system to trace raw material is required 

under section 4.3. Therefore, both 

manufacturers and operators would 

need to keep adequate records. The 

ultimate responsibility for verifying the 

type of pipe actually used would rest 

with the operator. 

A member of the liquid committee 

provided comments on behalf of 

NAPSR, stating that the PHMSA 

presentation adequately described 

NAPSR’s concerns. The member stated 

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that NAPSR feels the ratepayers pay for 

good pipe that’s made of virgin material 

and should last not just a few years, but, 

if constructed properly, for the next 100 

years. With that, NAPSR was opposed to 

any use of rework for construction of 

plastic pipe for gas. 

D. PHMSA Position on Rework 

At the February advisory committee 

meetings, a PHMSA staff member 

provided more background information 

on rework and described the differences 

in the three versions of the standards 

proposed. He also presented additional 

technical and field perspective on issues 

surrounding rework itself, as well as 

applicable requirements or guidance 

found in ASTM D2513–09a and PPI 

TN–30. Among the new technical 

information presented, the PHMSA staff 

member provided information from 

several other reports: ‘‘Analysis of 

Microscopic Leaks in Polyethylene Gas 

Distribution Piping’’ by Electric Power 

Research Institute (EPRI); 

‘‘Electrochemical Treeing in Cable’’ by 

Phelps Dodge Cable and Wire Company 

(January 1978); and ‘‘Deterioration of 

Water Immersed Polyethylene-Coated 

Wire by Treeing’’ by Takao Miyashita 

(IEEE Member) (March 1971). 

These reports indicated that rework 

could potentially be an issue of concern, 

particularly through breakdown of 

dielectric properties, the development 

of pinhole leaks, and static discharge. 

The PHMSA staff member restated 

several of the technical issues 

referenced in the OTD report, 

‘‘Evaluation of Impact of Rework,’’ 

mentioned by several commenters and 

indicating that rework was not an issue. 

The PHMSA staff member did 

acknowledge that none of the reports 

mentioned thus far was definitive, one 

way or another. The PHMSA staff 

member presented information on the 

extent to which other countries and 

industries allow rework. Previous 

comments from manufacturers indicated 

no other country or industry prohibits 

rework, and the U.S. (through PHMSA) 

would be the first to do so. In the United 

States, the nuclear industry does not 

allow scrap or regrind material per Code 

Case N–755. While the Code Case is not 

directly incorporated under Title 10, in 

part because plastic is newer to the 

nuclear industry and there may be some 

other issues with the Code Case, anyone 

who wants to use plastic instead of steel 

in the nuclear industry needs to present 

technical information to justify the use 

of plastic. It is typically expected that 

anyone who wants to use plastic pipe 

must comply with N–755, including not 

allowing the use of regrind material. 

The electric industry has also 

experienced poor performance on 

insulation materials and effects from 

contamination and has developed better 

standards and quality-control 

procedures. A listing of references to 

additional reports was provided and is 

available on the meeting Web site and 

on the docket. For other countries, the 

PHMSA staff member noted that Canada 

is considering prohibiting rework 

through a standard being developed by 

the CSA. The PHMSA staff member also 

understood many foreign operators do 

not allow rework. 

After reviewing the comments and 

materials provided, PHMSA is not 

convinced there is adequate justification 

to allow rework materials (section 4.2 of 

ASTM D2513–09a) for PE pipe at this 

time. PHMSA believes commenters did 

not make it clear how incorporating the 

standard in its entirety for all PE piping 

would provide an equivalent level of 

safety or better. It appears there is more 

evidence indicating that the exclusion 

of rework would provide increased 

safety for operators due to the concern 

of contamination of the materials during 

the manufacturing process and, 

therefore, contaminating the new pipe. 

Comments received concerning 

potential costs associated with 

prohibiting rework entirely may not 

have taken all relevant factors into 

account (e.g., how many operators are 

actually allowing rework materials). 

PHMSA believes the commenters may 

have also overestimated the cost impact 

on manufacturers because the results 

appear to be based on the assumptions 

that rework is currently allowed by all 

pipeline operators. PHMSA has learned 

however, from comments made by the 

AGA, NAPSR, and an advisory 

committee industry member that some 

operators currently prohibit rework for 

piping under a certain diameter, with 

many operators already requiring the 

use of virgin plastic pipe only. The 

available data based on industry-wide 

practices and action costs does not 

appear to indicate a significant increase 

in costs to manufacturers or operators. 

If some additional costs are incurred 

to improve quality control and 

assurance processes, PHMSA believes 

any improvements in manufacturing 

quality assurance/quality control are 

likely to be outweighed by the benefits 

for pipeline safety. 

Some commenters stated reworked 

material is sometimes used for 

alternative purposes such as blow 

molding. The PPI suggested there is no 

other market for medium-density PE 

pipe other than gas distribution. 

PHMSA believes additional guidance 

on manufacturing procedures could 

possibly reduce the amount of scrap 

used for rework material. The ASTM is 

currently developing a standard for the 

proper use of rework, and a recent 

revision to PPI TN–30 provides good 

recommendations for materials 

handling. 

While PPI’s concerns related to oil 

and gas gathering lines may have some 

validity, and there may be a time when 

more oil and gas gathering lines could 

become regulated, any such discussions 

are outside the scope of this rulemaking. 

PHMSA does, however, commit to 

engage with the manufacturers and 

other relevant stakeholders when 

discussing the use of plastic materials in 

oil and gas gathering lines. 

PHMSA stands by its original 

proposal to incorporate ASTM D2513– 

09a for PE pipe and continue to 

reference ASTM D2513–99 for non-PE 

plastic pipe but prohibit the use of 

rework material. PHMSA will also 

continue to reference ASTM D2513–87 

for marking only of non-PE plastic pipe. 

V. Public Availability of Standards 

All incorporated by reference 

documents addressed in this rule are 

available for visual inspection, as 

required by Section 24 of Public Law 

112–90, January 3, 2012, and amended 

49 U.S.C. 60102 on January 3, 2013 at 

the following locations: 

—The U.S. Department of 

Transportation, Pipeline and 

Hazardous Materials Safety 

Administration, Office of Pipeline 

Safety, 1200 New Jersey Avenue SE., 

Washington, DC 20590–0001 or any of 

PHMSA’s five regional offices 

(addresses available at: http://

www.phmsa.dot.gov/pipeline/about/

org); 

—The National Archives and Records 

Administration (NARA), Office of the 

Federal Register (NF), 8601 Adelphi 

Road, College Park, MD 20740–6001. 

For information on the availability of 

this material at NARA, call 202–741– 

6030 or go to: http://

www.archives.gov/federal-register/

code-of-federal-regulations/ibrlocations.html; and 

—The respective standards developing 

organizations (SDO) listed in Parts 

192, 193, and 195. If you want to view 

the standards for free or purchase 

copies of the standards incorporated 

by reference, they are available from 

each of the SDOs listed above and 

may also be available on the open 

market. With this rule, the SDO Web 

sites have been added to the listing of 

documents incorporated by reference 

in each part. 

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VI. Regulatory Analyses and Notices 

A. Summary/Legal Authority for This 

Rulemaking 

This final rule is published under the 

authority of the Federal pipeline safety 

law (49 U.S.C. 60101 et seq.). Section 

60102 authorizes the Secretary of 

Transportation to issue regulations 

governing the design, installation, 

inspection, emergency plans and 

procedures, testing, construction, 

extension, operation, replacement, and 

maintenance of pipeline facilities. 

Further, 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 a part of the Federal pipeline 

safety regulations. This final rule 

incorporates by reference two new 

editions (one partially incorporated) and 

21 updated standards of those currentlyreferenced standards (wholly or in part). 

In addition, this final rule makes several 

other miscellaneous and editorial 

changes to the pipeline safety 

regulations. 

B. Executive Order 12866, Executive 

Order 13563, and DOT Regulatory 

Policies and Procedures 

This final rule is not considered a 

significant regulatory action under 

section 3(f) of Executive Order 12866 

(58 FR 51735) and, therefore, was not 

subject to review by the Office of 

Management and Budget (OMB). This 

final rule is considered non-significant 

under the Regulatory Policies and 

Procedures of the Department of 

Transportation (44 FR 11034). 

In accordance with the National 

Technology and Advancement Act of 

1995 (‘‘the Act’’) and OMB Circular 

A–119, ‘‘Federal Participation in the 

Development and Use of Voluntary 

Consensus Standards and in Conformity 

Assessment Activities,’’ PHMSA 

constantly reviews new editions and 

revisions to relevant standards and 

publishes a proposed rule every 2 years 

to incorporate by reference new or 

updated consensus standards. This 

practice is consistent with the intent of 

the Act and OMB directives to avoid the 

need for developing government-written 

standards that could potentially result 

in regulatory conflicts with updated 

standards and an increased compliance 

burden on industry. In this final rule, 

PHMSA also incorporates by reference 

two new standards, API RP 5LT and 

ASTM D2513–09a (excluding section 

4.2—Rework Material), and updates 21 

currently referenced standards and 

specifications in 49 CFR parts 192, 193, 

and 195. 

According to the annual reports 

pipeline operators submit to PHMSA, 

there are over 2,370 entities operating 

hazardous liquid, natural gas 

transmission, gathering, distribution 

systems, and liquefied natural gas 

facilities as of December 31, 2011. The 

amendments in this rule should 

enhance safety and reduce the 

compliance burden on the regulated 

industry. 

PHMSA estimates the costs of 

incorporating these standards to be 

negligible and the net benefits to be 

high. In fact, industry standards 

developed and adopted by consensus 

are largely accepted and followed by the 

pipeline industry, which assures that 

the industry is not forced to comply 

with a number of different standards to 

accomplish the same safety goal. The 

majority of pipeline operators already 

purchase and apply industry standards 

as part of common business practice. 

In addition to incorporating new and 

updating existing voluntary consensus 

standards, PHMSA is making nonsubstantive edits and clarifying 

regulatory language in certain 

provisions. Since these editorial 

changes are relatively minor, this rule 

would not require pipeline operators to 

undertake significant new pipeline 

safety initiatives and would have 

negligible cost implications. The nonsubstantive changes will increase the 

clarity of the pipeline safety regulations, 

and help improve compliance, and 

improve the safety of the nation’s 

pipeline systems. 

Executive Order 13563 is 

supplemental to and reaffirms the 

principles, structures, and definitions 

governing regulatory review that were 

established in Executive Order 12866, 

Regulatory Planning and Review, of 

September 30, 1993. Additionally, 

Executive Order 13563 specifically 

requires agencies to: (1) Involve the 

public in the regulatory process; (2) 

promote simplification and 

harmonization through interagency 

coordination; (3) identify and consider 

regulatory approaches that reduce 

burden and maintain flexibility; (4) 

ensure the objectivity of any scientific 

or technological information used to 

support regulatory action; and (5) 

consider how to best promote 

retrospective analysis to modify, 

streamline, expand, or repeal existing 

rules that are outmoded, ineffective, 

insufficient, or excessively burdensome. 

When developing this rule, PHMSA 

involved the public in the regulatory 

process in a variety of ways. 

Specifically, PHMSA addressed issues 

and errors that were identified and 

tagged for future rulemaking 

consideration in letters from the 

regulated community and through 

meetings and correspondence with 

stakeholders. PHMSA considered public 

comments based on the proposals in the 

NPRM, addressed those comments in 

the docket, and discussed the proposals 

with the members of its two advisory 

committees and public representatives 

in attendance. 

These standards are expected to 

produce a safety benefit derived from 

new requirements with minimal 

additional costs. 

C. Executive Order 13132 

PHMSA analyzed this final rule in 

accordance with the principles and 

criteria contained in Executive Order 

13132 (‘‘Federalism’’). The final rule 

does 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 final rule 

does not impose substantial direct 

compliance costs on state and local 

governments nor will it preempt state 

law for intrastate pipelines. Therefore, 

the consultation and funding 

requirements of Executive Order 13132 

do not apply. 

D. Executive Order 13175 

PHMSA analyzed the final rule 

according to Executive Order 13175, 

‘‘Consultation and Coordination with 

Indian Tribal Governments.’’ Because 

the final rule does 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 do not apply. 

E. Regulatory Flexibility Act, Executive 

Order 13272 and DOT Procedures and 

Policies 

The Regulatory Flexibility Act (5 

U.S.C. 601 et seq.), requires an agency 

to review regulations to assess their 

impact on small entities, unless the 

agency determines the rule is not 

expected to have a significant impact on 

a substantial number of small entities. 

An example of a small business may 

include technical experts from a 

publicly owned natural gas local 

distribution company. 

Technical committees that develop 

codes and standards are, for the most 

part, comprised of experts representing 

the various facets of a given industry, 

such as manufacturers, installers, 

insurers, inspectors, end users, 

distributors and regulatory agencies. 

Participants represent both large and 

small businesses and others. An 

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example of the make-up of a typical 

standards committee may include 

representatives (engineers, researchers, 

or risk management officers) from large 

and small operating companies, 

government members (Federal/state), 

risk management consultants, insurance 

administrators, academics and 

individuals. Meetings are open to the 

public. The committees involved in 

developing, revising, and approving 

consensus standards created by 

organizations such as the API or AGA 

include technical experts, operating 

companies, vendors, consultants, 

academics, and regulators. 

The impact of this final rule will not 

have a significant impact on compliance 

cost regardless of the size of the firm. 

The changes update current editions of 

industry standards to allow for the use 

of newer or updated safety procedures 

to promote uniformity among industry 

practices. Changes in standards 

employing performance-based 

approaches have resulted in fewer 

costly changes to an organization’s 

manufacturing processes. 

Consideration of alternative proposals 

for small businesses: The Regulatory 

Flexibility Act directs agencies to 

establish expectations and differing 

compliance standards for small 

businesses, where it is possible to do so, 

while still meeting the objectives of 

applicable regulatory statutes. In the 

case of hazardous liquid, natural gas 

and other types of materials transported 

by pipeline, any exceptions are 

considered during the rulemaking 

process. For the most part, differing 

standards are not possible due to the 

type of technical requirements covered 

by these standards. The impact of this 

final rule will be minimal. The changes 

are intended to provide industry 

guidance through adoption of newer 

editions of consensus standards and 

recommended practices. 

Based on the facts available about the 

anticipated impact of this rulemaking, I 

certify, under Section 605 of the 

Regulatory Flexibility Act (5 U.S.C. 

605), that this final rule will not have a 

significant economic impact on a 

substantial number of small entities. 

F. Paperwork Reduction Act 

This final rule does not impose any 

new information collection 

requirements. 

G. Regulation Identifier Number 

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. 

H. Unfunded Mandates Reform Act of 

1995 

This final rule will not impose 

unfunded mandates under the 

Unfunded Mandates Reform Act of 

1995. It will not result in costs of $100 

million (adjusted for inflation currently 

estimated to be $132 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 this final rule. 

I. 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, etc.). 

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/. 

J. Environmental Assessment 

The National Environmental Policy 

Act of 1969, 42 U.S.C. 4321–4375, 

requires Federal agencies to analyze 

proposed actions to determine whether 

the action will have a significant impact 

on the human environment. The 

Council on Environmental Quality 

regulations require 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)). In this final rule, PHMSA 

incorporates two new standards (one 

partially) and incorporates 21 updated 

standards of those currently referenced. 

This final rule also makes miscellaneous 

and editorial changes to the pipeline 

safety regulations. 

Description of Action: The National 

Technology Transfer and Advancement 

Act of 1995 directs Federal agencies to 

use voluntary consensus standards and 

design specifications developed by 

voluntary consensus standard bodies 

instead of government-developed 

voluntary technical standards, when 

applicable. There are currently 64 

standards incorporated by reference in 

Parts 192, 193 and 195 of the pipeline 

safety regulations. 

PHMSA engineers and subject matter 

experts participate on approximately 25 

standards development committees to 

keep current on committee actions. 

PHMSA will only propose to adopt 

standards into the Federal regulations 

that meet the agency’s directive(s) to 

ensure the best interests of public and 

environmental safety are served. 

Purpose and Need: Many of the 

industry standards currently 

incorporated by reference in the 

pipeline safety regulations have been 

revised and updated to incorporate and 

promote new technologies and 

methodologies. This final rule will 

allow operators to use new technologies 

by incorporating new editions of the 

standards into the pipeline safety 

regulations. 

PHMSA’s technical experts 

continually review the actions of 

pipeline standards developing 

committees and study industry safety 

practices to ensure that their 

endorsement of any new editions or 

revised standards incorporated into the 

Federal safety regulations will improve 

public safety, as well as provide 

protection for the environment. If 

PHMSA does not amend the Federal 

safety standards to keep up with 

industry practices, it could potentially 

have an adverse effect on the 

transportation of energy resources. 

These amendments will make the 

regulatory provisions more consistent 

with current technology and will 

therefore promote the safe 

transportation of hazardous liquids, 

natural and other gases and liquefied 

natural gas by pipeline. 

Alternatives Considered: In 

developing this final rule, PHMSA 

considered two alternatives: 

Alternative (1): Take no action and 

continue to incorporate the existing 

standards currently referenced in the 

pipeline safety regulations. 

Because PHMSA’s goal is to facilitate 

pipeline safety, PHMSA rejected the 

alternative to take no action. 

Alternative (2): Go forward with the 

proposed amendments and incorporate 

updated editions of voluntary consensus 

standards to allow pipeline operators to 

use current technologies. This is the 

selected alternative. 

PHMSA’s goal is to incorporate by 

reference all or parts of updated editions 

of voluntary consensus standards into 

the pipeline safety regulations to allow 

pipeline operators to use current 

technology, new materials, and other 

industry and management practices. 

Another goal is to update and clarify 

certain provisions in the regulations. 

Environmental Consequences: The 

Nation’s pipelines are located 

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178 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

throughout the United States, both 

onshore and offshore, and traverse a 

variety of environments—from highly 

populated urban sites to remote, 

unpopulated rural areas. The Federal 

pipeline regulatory system is a risk 

management system that is preventionoriented and focused on identifying 

safety hazards and reducing the 

probability and quantity of a natural gas 

or hazardous liquid release. Pipeline 

operators are required to develop and 

implement IM programs to enhance 

safety by identifying and reducing 

pipeline integrity risks. 

Pipelines subject to this final rule 

transport hazardous liquids and natural 

gas, and therefore a spill or leak of the 

product could affect the physical 

environment as well as the health and 

safety of the public. The release of 

hazardous liquids or natural gas can 

cause the loss of cultural and historical 

resources (e.g., properties listed on the 

National Register of Historic Places), 

biological and ecological resources (e.g., 

coastal zones, wetlands, plant and 

animal species and their habitats, 

forests, grasslands, offshore marine 

ecosystems), special ecological 

resources (e.g., threatened and 

endangered plant and animal species 

and their habitats, national and state 

parklands, biological reserves, wild and 

scenic rivers), and the contamination of 

air, water resources (e.g., oceans, 

streams, lakes), and soil that exist 

directly adjacent to and within the 

vicinity of pipelines. Incidents 

involving pipelines can result in fires 

and explosions, causing damage to the 

local environment. Depending on the 

size of a spill or gas leak and the nature 

of the failure zone, the potential impacts 

could vary from property damage or 

environmental damage, injuries or, on 

rare occasions, fatalities. 

Compliance with the pipeline safety 

regulations substantially reduces the 

possibility of an accidental release of 

product. Updating new industry 

standards or those already incorporated 

into the pipeline safety regulations 

provides operators with the advantage 

and added safety of applying newer 

technologies. These standards are based 

on the accumulated knowledge and 

experience of owners, operators, 

manufacturers, risk management experts 

and others involved in the pipeline 

industry or government agencies who 

write the regulations to ensure the 

products are moved safely throughout 

the country. PHMSA staff actively 

participates in the standards 

development process to ensure each 

standard incorporated will enhance 

safety and environmental protection. 

Newer editions are not automatically 

incorporated but reviewed in detail. 

PHMSA reviewed each of the standards 

described in this rule and have 

determined that the majority of the 

updates include nearly minor changes 

such as editorial changes, inclusion of a 

best practices, or similar changes. 

The discussion of the standards 

PHMSA has chosen not to incorporate at 

this time or that are to be partial 

incorporated is included under section 

II of this rule. 

Conclusion—Degree of Environmental 

Impact: PHMSA incorporates consensus 

standards that will allow the pipeline 

industry to use improved technologies, 

new materials, performance-based 

approaches, manufacturing processes, or 

other practices to enhance public 

health, safety and welfare. PHMSA’s 

goal is to ensure hazardous liquids, 

natural and other gases and liquefied 

natural gas transported by pipeline will 

arrive safely to its destination. 

PHMSA has determined that the 

selected alternative will not have a 

significant impact on the environment. 

K. Executive Order 13211 

Transporting gas and petroleum 

affects the Nation’s available energy 

supply. However, this final rule 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 likely 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 final 

rule as a significant energy action. 

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. 

49 CFR Part 198 

Grant programs—transportation, 

Pipeline safety, Reporting and 

recordkeeping requirements. 

49 CFR Part 199 

Drug and alcohol testing. 

In consideration of the foregoing, 

PHMSA amends 49 CFR parts 192, 193, 

195, 198, and 199 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 1.97. 

§§ 192.923, 192.925, 192.931, 192.935, 

192.939 [Amended] 

■ 2. In 49 CFR part 192, remove the term 

‘‘NACE SP0502–2008’’ and add in its 

place ‘‘NACE SP0502’’ everywhere it 

appears in the following sections: 

■ a. Section 192.923(b)(1); 

■ b. Section 192.925(b) introductory 

text; 

■ c. Section 192.925(b)(1) introductory 

text; 

■ d. Section 192.925(b)(1)(ii); 

■ e. Section 192.925(b)(2) introductory 

text; 

■ f. Section 192.925(b)(3) introductory 

text; 

■ g. Section 192.925(b)(3)(ii)(A); 

■ h. Section 192.925(b)(3)(ii)(B); 

■ i. Section 192.925(b)(3)(iv); 

■ j. Section 192.925(b)(4) introductory 

text; 

■ k. Section 192.925(b)(4)(ii); 

■ l. Section 192.931(d); 

■ m. Section 192.935(b)(1)(iv); 

■ n. Section 192.939(a)(2). 

■ 3. Section 192.7 is revised to read as 

follows: 

§ 192.7 What documents are incorporated 

by reference partly or wholly in this part? 

(a) This part prescribes standards, or 

portions thereof, incorporated by 

reference into this part with the 

approval of the Director of the Federal 

Register in 5 U.S.C. 552(a) and 1 CFR 

part 51. The materials listed in this 

section have the full force of law. To 

enforce any edition other than that 

specified in this section, PHMSA must 

publish a notice of change in the 

Federal Register. 

(1) Availability of standards 

incorporated by reference. All of the 

materials incorporated by reference are 

available for inspection from several 

sources, including the following: 

(i) The Office of Pipeline Safety, 

Pipeline and Hazardous Materials Safety 

Administration, 1200 New Jersey 

Avenue SE., Washington, DC 20590. For 

more information contact 202–366–4046 

or go to the PHMSA Web site at: http:// 

www.phmsa.dot.gov/pipeline/regs. 

(ii) The National Archives and 

Records Administration (NARA). For 

information on the availability of this 

material at NARA, call 202–741–6030 or 

go to the NARA Web site at: http://

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www.archives.gov/federal_register/

code_of_federal_regulations/ibr_

locations.html. 

(iii) Copies of standards incorporated 

by reference in this part can also be 

purchased or are otherwise made 

available from the respective standardsdeveloping organization at the addresses 

provided in the centralized IBR section 

below. 

(2) [Reserved] 

(b) American Petroleum Institute 

(API), 1220 L Street NW., Washington, 

DC 20005, phone: 202–682–8000, http:// 

api.org/. 

(1) API Recommended Practice 5L1, 

‘‘Recommended Practice for Railroad 

Transportation of Line Pipe,’’ 7th 

edition, September 2009, (API RP 5L1), 

IBR approved for § 192.65(a). 

(2) API Recommended Practice 5LT, 

‘‘Recommended Practice for Truck 

Transportation of Line Pipe,’’ First 

edition, March 2012, (API RP 5LT), IBR 

approved for § 192.65(c). 

(3) API Recommended Practice 5LW, 

‘‘Recommended Practice for 

Transportation of Line Pipe on Barges 

and Marine Vessels,’’ 3rd edition, 

September 2009, (API RP 5LW), IBR 

approved for § 192.65(b). 

(4) API Recommended Practice 80, 

‘‘Guidelines for the Definition of 

Onshore Gas Gathering Lines,’’ 1st 

edition, April 2000, (API RP 80), IBR 

approved for § 192.8(a). 

(5) API Recommended Practice 1162, 

‘‘Public Awareness Programs for 

Pipeline Operators,’’ 1st edition, 

December 2003, (API RP 1162), IBR 

approved for § 192.616(a), (b), and (c). 

(6) API Recommended Practice 1165, 

‘‘Recommended Practice for Pipeline 

SCADA Displays,’’ First edition, January 

2007, (API RP 1165), IBR approved for 

§ 192.631(c). 

(7) API Specification 5L, 

‘‘Specification for Line Pipe,’’ 45th 

edition, effective July 1, 2013, (API Spec 

5L), IBR approved for §§ 192.55(e); 

192.112(a), (b), (d), (e); 192.113; and 

Item I, Appendix B to Part 192. 

(8) ANSI/API Specification 6D, 

‘‘Specification for Pipeline Valves,’’23rd 

edition, effective October 1, 2008, 

including Errata 1 (June 2008), Errata2 

(/November 2008), Errata 3 (February 

2009), Errata 4 (April 2010), Errata 5 

(November 2010), Errata 6 (August 

2011) Addendum 1 (October 2009), 

Addendum 2 (August 2011), and 

Addendum 3 (October 2012), (ANSI/API 

Spec 6D), IBR approved for § 192.145(a). 

(9) API Standard 1104, ‘‘Welding of 

Pipelines and Related Facilities,’’ 20th 

edition, October 2005, including errata/ 

addendum (July 2007) and errata 2 

(2008), (API Std 1104), IBR approved for 

§§ 192.225(a); 192.227(a); 192.229(c); 

192.241(c); and Item II, Appendix B. 

(c) ASME International (ASME), 

Three Park Avenue, New York, NY 

10016, 800–843–2763 (U.S./Canada), 

http://www.asme.org/. 

(1) ASME/ANSI B16.1–2005, ‘‘Gray 

Iron Pipe Flanges and Flanged Fittings: 

(Classes 25, 125, and 250),’’ August 31, 

2006, (ASME/ANSI B16.1), IBR 

approved for § 192.147(c). 

(2) ASME/ANSI B16.5–2003, ‘‘Pipe 

Flanges and Flanged Fittings, ‘‘October 

2004, (ASME/ANSI B16.5), IBR 

approved for §§ 192.147(a) and 192.279. 

(3) ASME/ANSI B31G–1991 

(Reaffirmed 2004), ‘‘Manual for 

Determining the Remaining Strength of 

Corroded Pipelines,’’ 2004, (ASME/

ANSI B31G), IBR approved for 

§§ 192.485(c) and 192.933(a). 

(4) ASME/ANSI B31.8–2007, ‘‘Gas 

Transmission and Distribution Piping 

Systems,’’ November 30, 2007, (ASME/ 

ANSI B31.8), IBR approved for 

§§ 192.112(b) and 192.619(a). 

(5) ASME/ANSI B31.8S–2004, 

‘‘Supplement to B31.8 on Managing 

System Integrity of Gas Pipelines,’’ 

2004, (ASME/ANSI B31.8S–2004), IBR 

approved for §§ 192.903 note to 

Potential impact radius; 192.907 

introductory text, (b); 192.911 

introductory text, (i), (k), (l), (m); 

192.913(a), (b), (c); 192.917 (a), (b), (c), 

(d), (e); 192.921(a); 192.923(b); 

192.925(b); 192.927(b), (c); 192.929(b); 

192.933(c), (d); 192.935 (a), (b); 

192.937(c); 192.939(a); and 192.945(a). 

(6) ASME Boiler & Pressure Vessel 

Code, Section I, ‘‘Rules for Construction 

of Power Boilers 2007,’’ 2007 edition, 

July 1, 2007, (ASME BPVC, Section I), 

IBR approved for § 192.153(b). 

(7) ASME Boiler & Pressure Vessel 

Code, Section VIII, Division 1 ‘‘Rules for 

Construction of Pressure Vessels,’’ 2007 

edition, July 1, 2007, (ASME BPVC, 

Section VIII, Division 1), IBR approved 

for §§ 192.153(a), (b), (d); and 

192.165(b). 

(8) ASME Boiler & Pressure Vessel 

Code, Section VIII, Division 2 

‘‘Alternate Rules, Rules for Construction 

of Pressure Vessels,’’ 2007 edition, July 

1, 2007, (ASME BPVC, Section VIII, 

Division 2), IBR approved for 

§§ 192.153(b), (d); and 192.165(b). 

(9) ASME Boiler & Pressure Vessel 

Code, Section IX: ‘‘Qualification 

Standard for Welding and Brazing 

Procedures, Welders, Brazers, and 

Welding and Brazing Operators,’’ 2007 

edition, July 1, 2007, ASME BPVC, 

Section IX, IBR approved for 

§§ 192.225(a); 192.227(a); and Item II, 

Appendix B to Part 192. 

(d) American Society for Testing and 

Materials (ASTM), 100 Barr Harbor 

Drive, PO Box C700, West 

Conshohocken, PA 19428, phone: (610) 

832–9585, Web site: http://

www.astm.org/. 

(1) ASTM A53/A53M–10, ‘‘Standard 

Specification for Pipe, Steel, Black and 

Hot-Dipped, Zinc-Coated, Welded and 

Seamless,’’ approved October 1, 2010, 

(ASTM A53/A53M), IBR approved for 

§ 192.113; and Item II, Appendix B to 

Part 192. 

(2) ASTM A106/A106M–10, 

‘‘Standard Specification for Seamless 

Carbon Steel Pipe for High-Temperature 

Service,’’ approved October 1, 2010, 

(ASTM A106/A106M), IBR approved for 

§ 192.113; and Item I, Appendix B to 

Part 192. 

(3) ASTM A333/A333M–11, 

‘‘Standard Specification for Seamless 

and Welded Steel Pipe for LowTemperature Service,’’ approved April 

1, 2011, (ASTM A333/A333M), IBR 

approved for § 192.113; and Item I, 

Appendix B to Part 192. 

(4) ASTM A372/A372M–10, 

‘‘Standard Specification for Carbon and 

Alloy Steel Forgings for Thin-Walled 

Pressure Vessels,’’ approved October 1, 

2010, (ASTM A372/A372M), IBR 

approved for § 192.177(b). 

(5) ASTM A381–96 (reapproved 

2005), ‘‘Standard Specification for 

Metal-Arc Welded Steel Pipe for Use 

with High-Pressure Transmission 

Systems,’’ approved October 1, 2005, 

(ASTM A381), IBR approved for 

§ 192.113; and Item I, Appendix B to 

Part 192. 

(6) ASTM A578/A578M–96 

(reapproved 2001), ‘‘Standard 

Specification for Straight-Beam 

Ultrasonic Examination of Plain and 

Clad Steel Plates for Special 

Applications,’’ (ASTM A578/A578M), 

IBR approved for § 192.112(c). 

(7) ASTM A671/A671M–10, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for 

Atmospheric and Lower Temperatures,’’ 

approved April 1, 2010, (ASTM A671/ 

A671M), IBR approved for § 192.113; 

and Item I, Appendix B to Part 192. 

(8) ASTM A672/A672M–09, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for HighPressure Service at Moderate 

Temperatures,’’ approved October 1, 

2009, (ASTM A672/672M), IBR 

approved for § 192.113 and Item I, 

Appendix B to Part 192. 

(9) ASTM A691/A691M–09, 

‘‘Standard Specification for Carbon and 

Alloy Steel Pipe, Electric-FusionWelded for High-Pressure Service at 

High Temperatures,’’ approved October 

1, 2009, (ASTM A691/A691M), IBR 

approved for § 192.113 and Item I, 

Appendix B to Part 192. 

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180 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

(10) ASTM D638–03, ‘‘Standard Test 

Method for Tensile Properties of 

Plastics,’’ 2003, (ASTM D638), IBR 

approved for § 192.283(a) and (b). 

(11) ASTM D2513–87, ‘‘Standard 

Specification for Thermoplastic Gas 

Pressure Pipe, Tubing, and Fittings,’’ 

(ASTM D2513–87), IBR approved for 

§ 192.63(a). 

(12) ASTM D2513–99, ‘‘Standard 

Specification for Thermoplastic Gas 

Pressure Pipe, Tubing, and Fittings,’’ 

(ASTM D 2513–99), IBR approved for 

§§ 192.191(b); 192.281(b); 192.283(a) 

and Item 1, Appendix B to Part 192. 

(13) ASTM D2513–09a, ‘‘Standard 

Specification for Polyethylene (PE) Gas 

Pressure Pipe, Tubing, and Fittings,’’ 

approved December 1, 2009, (ASTM 

D2513–09a), IBR approved for 

§§ 192.123(e); 192.191(b); 192.283(a); 

and Item 1, Appendix B to Part 192. 

(14) ASTM D2517–00, ‘‘Standard 

Specification for Reinforced Epoxy 

Resin Gas Pressure Pipe and Fittings,’’ 

(ASTM D 2517), IBR approved for 

§§ 192.191(a); 192.281(d); 192.283(a); 

and Item I, Appendix B to Part 192. 

(15) ASTM F1055–1998, ‘‘Standard 

Specification for Electrofusion Type 

Polyethylene Fittings for Outside 

Diameter Controller Polyethylene Pipe 

and Tubing,’’ (ASTM F1055), IBR 

approved for § 192.283(a). 

(e) Gas Technology Institute (GTI), 

formerly the Gas Research Institute 

(GRI)), 1700 S. Mount Prospect Road, 

Des Plaines, IL 60018, phone: 847–768– 

0500, Web site: www.gastechnology.org. 

(1) GRI 02/0057 (2002) ‘‘Internal 

Corrosion Direct Assessment of Gas 

Transmission Pipelines Methodology,’’ 

(GRI 02/0057), IBR approved for 

§ 192.927(c). 

(2) [Reserved] 

(f) Manufacturers Standardization 

Society of the Valve and Fittings 

Industry, Inc. (MSS), 127 Park St. NE., 

Vienna, VA 22180, phone: 703–281– 

6613, Web site: http://www.mss-hq. 

org/. 

(1) MSS SP–44–2010, Standard 

Practice, ‘‘Steel Pipeline Flanges,’’ 2010 

edition, (including Errata (May 20, 

2011)), (MSS SP–44), IBR approved for 

§ 192.147(a). 

(2) [Reserved] 

(g) NACE International (NACE), 1440 

South Creek Drive, Houston, TX 77084: 

phone: 281–228–6223 or 800–797–6223, 

Web site: http://www.nace.org/

Publications/. 

(1) ANSI/NACE SP0502–2010, 

Standard Practice, ‘‘Pipeline External 

Corrosion Direct Assessment 

Methodology,’’ revised June 24, 2010, 

(NACE SP0502), IBR approved for 

§§ 192.923(b); 192.925(b); 192.931(d); 

192.935(b) and 192.939(a). 

(2) [Reserved] 

(h) National Fire Protection 

Association (NFPA), 1 Batterymarch 

Park, Quincy, Massachusetts 02169, 

phone: 1 617 984–7275, Web site: 

http://www.nfpa.org/. 

(1) NFPA–30 (2012), ‘‘Flammable and 

Combustible Liquids Code,’’ 2012 

edition, June 20, 2011, including Errata 

30–12–1 (September 27, 2011) and 

Errata 30–12–2 (November 14, 2011), 

(NFPA–30), IBR approved for 

§ 192.735(b). 

(2) NFPA–58 (2004), ‘‘Liquefied 

Petroleum Gas Code (LP-Gas Code),’’ 

(NFPA–58), IBR approved for 

§ 192.11(a), (b), and (c). 

(3) NFPA–59 (2004), ‘‘Utility LP-Gas 

Plant Code,’’ (NFPA–59), IBR approved 

for § 192.11(a), (b); and (c). 

(4) NFPA–70 (2011), ‘‘National 

Electrical Code,’’ 2011 edition, issued 

August 5, 2010, (NFPA–70), IBR 

approved for §§ 192.163(e); and 

192.189(c). 

(i) Pipeline Research Council 

International, Inc. (PRCI), c/o Technical 

Toolboxes, 3801 Kirby Drive, Suite 520, 

P.O. Box 980550, Houston, TX 77098, 

phone: 713–630–0505, toll free: 866– 

866–6766, Web site: http://

www.ttoolboxes.com/. (Contract number 

PR–3–805.) 

(1) AGA, Pipeline Research 

Committee Project, PR–3–805, ‘‘A 

Modified Criterion for Evaluating the 

Remaining Strength of Corroded Pipe,’’ 

(December 22, 1989), (PRCI PR–3–805 

(R–STRENG)), IBR approved for 

§§ 192.485(c); 192.933(a) and (d). 

(2) [Reserved] 

(j) Plastics Pipe Institute, Inc. (PPI), 

105 Decker Court, Suite 825 Irving TX 

75062, phone: 469–499–1044, http://

www.plasticpipe.org/. 

(1) PPI TR–3/2008 HDB/HDS/PDB/

SDB/MRS Policies (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, ’’ May 2008, IBR 

approved for § 192.121. 

(2) [Reserved] 

§ 192.11 [Amended] 

■ 4. In § 192.11: 

■ a. Amend paragraph (a) by removing 

the term ‘‘ANSI/NFPA 58 and 59’’ and 

adding in its place the term ‘‘NFPA 58 

and 59 (incorporated by reference, see 

§ 192.7)’’. 

■ b. Amend paragraph (c) by removing 

the term ‘‘ANSI/NFPA 58 and 59, ANSI/ 

NFPA 58 and 59’’ and adding in its 

place the term ‘‘NFPA 58 and 59 

(incorporated by reference, see § 192.7), 

NFPA 58 and 59’’. 

§ 192.55 [Amended] 

■ 5. In § 192.55, amend paragraph (e) by 

removing the term ‘‘API Specification 

5L’’ and adding in its place the term 

‘‘API Spec 5L ‘‘(incorporated by 

reference, see § 192.7)’’. 

■ 6. In § 192.59, paragraph (d) is added 

to read as follows: 

§ 192.59 Plastic pipe. 

* * * * * 

(d) Rework and/or regrind material is 

not allowed in plastic pipe produced 

after March 6, 2015 used under this 

part. 

■ 7. In § 192.63, paragraph (a)(1) is 

revised to read as follows: 

§ 192.63 Marking of materials. 

(a) * * * 

(1) As prescribed in the specification 

or standard to which it was 

manufactured, except that thermoplastic 

pipe and fittings made of plastic 

materials other than polyethylene must 

be marked in accordance with ASTM 

D2513–87 (incorporated by reference, 

see § 192.7); 

* * * * * 

■ 8. Amend § 192.65 as follows: 

■ a. In paragraph (a)(1), remove the term 

‘‘API Recommended Practice 5L1’’ and 

add in its place the term ‘‘API RP 5L1’’. 

■ b. In paragraph (b), remove the term 

‘‘API Recommended Practice 5LW’’ and 

add in its place the term ‘‘API RP 5LW’’. 

■ c. Add a new paragraph (c) to read as 

follows: 

§ 192.65 Transportation of pipe. 

* * * * * 

(c) Truck. 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 truck unless the 

transportation is performed in 

accordance with API RP 5LT 

(incorporated by reference, see § 192.7). 

§ 192.112 [Amended] 

■ 9. Amend § 192.112: 

■ a. In paragraphs (a)(4), (b)(1)(i), 

(b)(1)(iii), (d)(1), and (e)(1) by removing 

the term ‘‘API Specification 5L’’ and 

adding in its place the term ‘‘API Spec 

5L’’. 

■ b. In paragraph (c)(2)(i) by removing 

the term, ‘‘API 5L’’ and adding in its 

place the term ‘‘API Spec 5L’’. 

§ 192.113 [Amended] 

■ 10. In the Table of § 192.113, remove 

the term ‘‘API 5 L’’ and add in its place 

the term ‘‘API Spec 5L’’. 

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Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 181 

§ 192.123 [Amended] 

■ 11. In § 192.123, revise paragraph 

(e)(2) to read as follows: 

§ 192.123 Design limitations for plastic 

pipe. 

* * * * * 

(e) * * * 

(2) The material is a polyethylene (PE) 

pipe with the designation code as 

specified within ASTM D2513–09a 

(incorporated by reference, see § 192.7); 

* * * * * 

§ 192.145 [Amended] 

■ 12. Amend § 192.145 paragraph (a) by 

removing the term ‘‘API 6D’’ and adding 

in its place the term ‘‘ANSI/API Spec 

6D’’. 

§ 192.147 [Amended] 

■ 13. Amend § 192.147 as follows: 

■ a. In paragraph (a), remove the phrase 

‘‘ASME/ANSI B 16.5, MSS SP–44’’ and 

add in its place the phrase ‘‘ASME/

ANSI B 16.5 and MSS SP–44 

(incorporated by reference, see 

§ 192.7)’’. 

■ b. In paragraph (c), remove the term 

‘‘ASME/ANSI B16.1’’ and add in its 

place the term ‘‘ASME/ANSI B16.1 

(incorporated by reference, see 

§ 192.7)’’. 

■ 14. In § 192.153, revise paragraphs (a), 

(b), and (d) to read as follows: 

§ 192.153 Components fabricated by 

welding. 

(a) Except for branch connections and 

assemblies of standard pipe and fittings 

joined by circumferential welds, the 

design pressure of each component 

fabricated by welding, whose strength 

cannot be determined, must be 

established in accordance with 

paragraph UG–101 of the ASME Boiler 

and Pressure Vessel Code (BPVC) 

(Section VIII, Division 1) (incorporated 

by reference, see § 192.7). 

(b) Each prefabricated unit that uses 

plate and longitudinal seams must be 

designed, constructed, and tested in 

accordance with section 1 of the ASME 

BPVC (Section VIII, Division 1 or 

Section VIII, Division 2) (incorporated 

by reference, see § 192.7), except for the 

following: 

* * * * * 

(d) Except for flat closures designed in 

accordance with the ASME BPVC 

(Section VIII, Division 1 or 2), flat 

closures and fish tails may not be used 

on pipe that either operates at 100 p.s.i. 

(689 kPa) gage or more, or is more than 

3 inches in (76 millimeters) nominal 

diameter. 

§ 192.163 [Amended] 

■ 15. Amend § 192.163 paragraph (e) by 

removing the term ‘‘National Electrical 

Code, ANSI/NFPA 70’’ and adding in its 

place ‘‘NFPA–70’’. 

§ 192.165 [Amended] 

■ 16. Amend § 192.165 paragraph (b)(3) 

by removing the term ‘‘ASME Boiler and 

Pressure Vessel Code’’ and adding in its 

place the term ‘‘ASME Boiler and 

Pressure Vessel Code (BPVC) 

(incorporated by reference, see 

§ 192.7)’’. 

§ 192.177 [Amended] 

■ 17. Amend § 192.177 paragraph (b)(1) 

by removing the term ‘‘ASTM A 372/

372’’ and adding in its place the term 

‘‘ASTM A372/372M (incorporated by 

reference, see § 192.7)’’. 

§ 192.189 [Amended] 

■ 18. Amend § 192.189 paragraph (c) by 

removing the reference ‘‘ANSI/NFPA 

70’’ and adding in its place the term 

‘‘NFPA–70 (incorporated by reference, 

see § 192.7)’’. 

§ 192.191 [Amended] 

■ 19. In § 192.191, paragraph (b) is 

revised to read as follows: 

§ 192.191 Design pressure of plastic 

fittings. 

* * * * * 

(b) Thermoplastic fittings for plastic 

pipe must conform to ASTM D2513–99 

for plastic materials other than 

polyethylene or ASTM D2513–09a for 

polyethylene plastic materials. 

§ 192.225 [Amended] 

■ 20. Amend § 192.225, paragraph (a) is 

amended as follows: 

■ a. Remove the term ‘‘API 1104’’ and 

add in its place the term ‘‘API Std 

1104’’. 

■ b. Remove the term ‘‘ASME Boiler and 

Pressure Vessel Code, ‘Welding and 

Brazing Qualifications’’’ and add in its 

place the term ‘‘ASME Boiler and 

Pressure Vessel Code (BPVC)’’. 

§ 192.227 [Amended] 

■ 21. In § 192.227, paragraph (a) is 

amended as follows: 

■ a. Remove the term ‘‘API 1104’’ and 

add in its place the term ‘‘API Std 

1104’’. 

■ b. Remove the term ‘‘ASME Boiler and 

Pressure Vessel Code’’ and add in its 

place the term ‘‘ASME Boiler and 

Pressure Vessel Code (BPVC)’’. 

§ 192.229 [Amended] 

■ 22. Amend § 192.229 paragraph (c)(1) 

by removing the term ‘‘API Standard 

1104’’ and adding in its place the term 

‘‘API Std 1104’’. 

§ 192.241 [Amended] 

■ 23. Amend § 192.241 paragraph (c) by 

removing the terms ‘‘API Standard 

1104’’ and ‘‘API 1104’’ and adding in 

their place the term ‘‘API Std 1104’’. 

§ 192.281 [Amended] 

■ 24. Amend § 192.281 paragraph (d)(1) 

by removing the term ‘‘ASTM 

Designation D 2517’’ and adding in its 

place the term ‘‘ASTM D 2517 

(incorporated by reference, see 

§ 192.7)’’. 

■ 25. Amend § 192.283 as follows: 

■ a. Revise paragraph (a)(1)(i) to read as 

set forth below. 

■ b. Amend paragraph (a)(1)(iii) by 

removing the term ‘‘ASTM Designation 

F1055 (incorporated by reference, see 

§ 192.7)’’ and adding in its place the 

term ‘‘ASTM F1055 (incorporated by 

reference, see § 192.7)’’. 

§ 192.283 Plastic pipe: Qualifying joining 

procedures. 

(a) * * * 

(1) * * * 

(i) In the case of thermoplastic pipe, 

paragraph 6.6 (Sustained Pressure Test) 

or paragraph 6.7 (Minimum Hydrostatic 

Burst Test) of ASTM D2513–99 for 

plastic materials other than 

polyethylene or ASTM D2513–09a 

(incorporated by reference, see § 192.7) 

for polyethylene plastic materials; 

* * * * * 

§ 192.485 [Amended] 

■ 26. Amend § 192.485 paragraph (c) as 

follows: 

■ a. Remove the term ‘‘ASME/ANSI 

B31G’’ and add in its place the term 

‘‘ASME/ANSI B31G (incorporated by 

reference, see § 192.7)’’. 

■ b. Remove the term ‘‘AGA Pipeline 

Research Committee Project PR 3–805 

(with RSTRENG disk)’’ and add in its 

place the term ‘‘PRCI PR 3–805 (R– 

STRENG) (incorporated by reference, 

see § 192.7)’’. 

§ 192.735 [Amended] 

■ 27. Amend § 192.735 paragraph (b) by 

removing the term ‘‘National Fire 

Protection Association Standard No. 30’’ 

and adding in its place the term 

‘‘NFPA–30 (incorporated by reference, 

see § 192.7)’’. 

§ 192.903 [Amended] 

■ 28. Amend the Note to Potential 

impact radius in § 192.903 by removing 

the term ‘‘ASME/ANSI B31.8S–2001 

(Supplement to ASME B31.8; 

incorporated by reference, see § 192.7)’’ 

and adding in its place the term 

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182 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

‘‘ASME/ANSI B31.8S (incorporated by 

reference, see § 192.7)’’. 

■ 29. In § 192.923, paragraphs (a) and 

(b) are revised to read as follows: 

§ 192.923 How is direct assessment used 

and for what threats? 

(a) General. An operator may use 

direct assessment either as a primary 

assessment method or as a supplement 

to the other assessment methods 

allowed under this subpart. An operator 

may only use direct assessment as the 

primary assessment method to address 

the identified threats of external 

corrosion (EC), internal corrosion (IC), 

and stress corrosion cracking (SCC). 

(b) Primary method. An operator 

using direct assessment as a primary 

assessment method must have a plan 

that complies with the requirements 

in— 

(1) Section 192.925 and ASME/ANSI 

B31.8S (incorporated by reference, see 

§ 192.7) section 6.4, and NACE SP0502 

(incorporated by reference, see § 192.7), 

if addressing external corrosion (EC). 

(2) Section 192.927 and ASME/ANSI 

B31.8S (incorporated by reference, see 

§ 192.7), section 6.4, appendix B2, if 

addressing internal corrosion (IC). 

(3) Section 192.929 and ASME/ANSI 

B31.8S (incorporated by reference, see 

§ 192.7), appendix A3, if addressing 

stress corrosion cracking (SCC). 

* * * * * 

■ 30. In § 192.933, revise paragraphs 

(a)(1) and (d)(1)(i) to read as follows: 

§ 192.933 What actions must be taken to 

address integrity issues? 

(a) * * * 

(1) Temporary pressure reduction. If 

an operator is unable to respond within 

the time limits for certain conditions 

specified in this section, the operator 

must temporarily reduce the operating 

pressure of the pipeline or take other 

action that ensures the safety of the 

covered segment. An operator must 

determine any temporary reduction in 

operating pressure required by this 

section using ASME/ANSI B31G 

(incorporated by reference, see § 192.7); 

Pipeline Research Council, 

International, PR–3–805 (R–STRENG) 

(incorporated by reference, see § 192.7); 

or by reducing the operating pressure to 

a level not exceeding 80 percent of the 

level at the time the condition was 

discovered. An operator must notify 

PHMSA in accordance with § 192.949 if 

it cannot meet the schedule for 

evaluation and remediation required 

under paragraph (c) of this section and 

cannot provide safety through a 

temporary reduction in operating 

pressure or through another action. An 

operator must also notify a State 

pipeline safety authority when either a 

covered segment is located in a State 

where PHMSA has an interstate agent 

agreement or an intrastate covered 

segment is regulated by that State. 

* * * * * 

(d) * * * 

(1) * * * 

(i) A calculation of the remaining 

strength of the pipe shows a predicted 

failure pressure less than or equal to 1.1 

times the maximum allowable operating 

pressure at the location of the anomaly. 

Suitable remaining strength calculation 

methods include ASME/ANSI B31G 

(incorporated by reference, see § 192.7), 

PRCI PR–3–805 (R–STRENG) 

(incorporated by reference, see § 192.7), 

or an alternative equivalent method of 

remaining strength calculation. 

* * * * * 

§ 192.939 [Amended] 

■ 31. Amend § 192.939 paragraph 

(a)(1)(ii) by removing the term ‘‘ASME/ 

ANSI B31.8S’’ and adding in its place 

the term ‘‘ASME B31.8S (incorporated 

by reference, see § 192.7)’’. 

■ 32. Amend Appendix B to Part 192 as 

follows: 

■ a. Revise Part I to read as set forth 

below. 

■ b. Amend the second paragraph of 

Part II.A, by removing the term ‘‘ASTM 

A53’’ and adding in its place the term 

‘‘ASTM A53/A53M’’. 

APPENDIX B TO PART 192— 

QUALIFICATION OF PIPE 

I. Listed Pipe Specifications 

ANSI/API Specification 5L—Steel pipe, 

‘‘Specification for Line Pipe’’ (incorporated 

by reference, see § 192.7). 

ASTM A53/A53M—Steel pipe, ‘‘Standard 

Specification for Pipe, Steel Black and HotDipped, Zinc-Coated, Welded and Seamless’’ 

(incorporated by reference, see § 192.7). 

ASTM A106/A106M—Steel pipe, 

‘‘Standard Specification for Seamless Carbon 

Steel Pipe for High Temperature Service’’ 

(incorporated by reference, see § 192.7). 

ASTM A333/A333M—Steel pipe, 

‘‘Standard Specification for Seamless and 

Welded Steel Pipe for Low Temperature 

Service’’ (incorporated by reference, see 

§ 192.7). 

ASTM A381—Steel pipe, ‘‘Standard 

Specification for Metal-Arc-Welded Steel 

Pipe for Use with High-Pressure 

Transmission Systems’’ (incorporated by 

reference, see § 192.7). 

ASTM A671/A671M—Steel pipe, 

‘‘Standard Specification for Electric-FusionWelded Pipe for Atmospheric and Lower 

Temperatures’’ (incorporated by reference, 

see § 192.7). 

ASTM A672/672M—Steel pipe, ‘‘Standard 

Specification for Electric-Fusion-Welded 

Steel Pipe for High-Pressure Service at 

Moderate Temperatures’’ (incorporated by 

reference, see § 192.7). 

ASTM A691/A691M—Steel pipe, 

‘‘Standard Specification for Carbon and Alloy 

Steel Pipe, Electric-Fusion-Welded for High 

Pressure Service at High Temperatures’’ 

(incorporated by reference, see § 192.7). 

ASTM D2513–99, ‘‘Standard Specification 

for Thermoplastic Gas Pressure Pipe, Tubing, 

and Fittings,’’ (incorporated by reference, see 

§ 192.7). 

ASTM D2513–09a—Polyethylene 

thermoplastic pipe and tubing, ‘‘Standard 

Specification for Polyethylene (PE) gas 

Pressure Pipe, Tubing, and Fittings’’, 

(incorporated by reference, see § 192.7). 

ASTM D2517—Thermosetting plastic pipe 

and tubing, ‘‘Standard Specification for 

Reinforced Epoxy Resin Gas Pressure Pipe 

and Fittings’’ (incorporated by reference, see 

§ 192.7). 

* * * * * 

PART 193—LIQUEFIED NATURAL GAS 

FACILITIES: FEDERAL SAFETY 

STANDARDS 

■ 33. 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. 

§§ 193.2019, 193.2051, 193.2057, 193.2301, 

193.2303, 193.2401, 193.2521, 193.2639, 

193.2639, and 193.2801 [Amended] 

■ 34. In 49 CFR part 193, remove the 

term ‘‘NFPA 59A’’ and add in its place 

‘‘NFPA–59A–2001’’ everywhere it 

appears in the following sections: 

■ a. Section 193.2019(a); 

■ b. Section 193.2051; 

■ c. Section 193.2057, introductory text; 

■ f. Section 193.2301; 

■ g. Section 193.2303; 

■ h. Section 193.2401; 

■ i. Section 193.2521; 

■ j. Section 193.2639(a); and 

■ k. Section 193.2801. 

■ 35. Section 193.2013 is revised to read 

as follows: 

§ 193.2013 What documents are 

incorporated by reference partly or wholly 

in this part? 

(a) This part prescribes standards, or 

portions thereof, incorporated by 

reference into this part with the 

approval of the Director of the Federal 

Register in 5 U.S.C. 552(a) and 1 CFR 

part 51. The materials listed in this 

section have the full force of law. To 

enforce any edition other than that 

specified in this section, PHMSA must 

publish a notice of change in the 

Federal Register. 

(1) Availability of standards 

incorporated by reference. All of the 

materials incorporated by reference are 

available for inspection from several 

sources, including the following: 

(i) The Office of Pipeline Safety, 

Pipeline and Hazardous Materials Safety 

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Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 183 

Administration, 1200 New Jersey 

Avenue SE., Washington, DC 20590. For 

more information contact 202–366–4046 

or go to the PHMSA Web site at: http:// 

www.phmsa.dot.gov/pipeline/regs. 

(ii) The National Archives and 

Records Administration (NARA). For 

information on the availability of this 

material at NARA, call 202–741–6030 or 

go to the NARA Web site at: http://

www.archives.gov/federal_register/

code_of_federal_regulations/ibr_

locations.html. 

(iii) Copies of standards incorporated 

by reference in this part can also be 

purchased or are otherwise made 

available from the respective standardsdeveloping organization at the addresses 

provided in the centralized IBR section 

below. 

(b) American Gas Association (AGA), 

400 North Capitol Street NW., 

Washington, DC 20001, and phone: 

202–824–7000, Web site: http://

www.aga.org/. 

(1) American Gas Association, 

‘‘Purging Principles and Practices,’’ 3rd 

edition, June 2001, (Purging Principles 

and Practices), IBR approved for 

§§ 193.2513(b) and (c), 193.2517, and 

193.2615(a). 

(2) [Reserved] 

(c) American Petroleum Institute 

(API), 1220 L Street NW., Washington, 

DC 20005, and phone: 202–682–8000, 

Web site: http://api.org/. 

(1) API Standard 620, ‘‘Design and 

Construction of Large, Welded, Lowpressure Storage Tanks,’’ 11th edition, 

February 2008 (including addendum 1 

(March 2009), addendum 2 (August 

2010), and addendum 3 (March 2012)), 

(API Std 620), IBR approved for 

§§ 193.2101(b); 193.2321(b). 

(2) [Reserved] 

(d) American Society of Civil 

Engineers (ASCE), 1801 Alexander Bell 

Drive, Reston, VA 20191, (800) 548– 

2723, 703 295–6300 (international), Web 

site: http://www.asce.org. 

(1) ASCE/SEI 7–05, ‘‘Minimum 

Design Loads for Buildings and Other 

Structures’’ 2005 edition (including 

supplement No. 1 and Errata), (ASCE/

SEI 7–05), IBR approved for 

§ 193.2067(b). 

(2) [Reserved] 

(e) ASME International (ASME), 

Three Park Avenue, New York, NY 

10016. 800–843–2763 (U.S/Canada), 

Web site: http://www.asme.org/. 

(1) ASME Boiler & Pressure Vessel 

Code, Section VIII, Division 1: ‘‘Rules 

for Construction of Pressure Vessels,’’ 

2007 edition, July 1, 2007, (ASME 

BPVC, Section VIII, Division 1), IBR 

approved for § 193.2321(a). 

(2) [Reserved] 

(f) Gas Technology Institute (GTI), 

formerly the Gas Research Institute 

(GRI), 1700 S. Mount Prospect Road, 

Des Plaines, IL 60018, phone: 847–768– 

0500, Web site: www.gastechnology.org. 

(1) GRI–96/0396.5, ‘‘Evaluation of 

Mitigation Methods for Accidental LNG 

Releases, Volume 5: Using FEM3A for 

LNG Accident Consequence Analyses,’’ 

April 1997, (GRI–96/0396.5), IBR 

approved for § 193.2059(a). 

(2) GTI–04/0032 LNGFIRE3: ‘‘A 

Thermal Radiation Model for LNG 

Fires’’ March 2004, (GTI–04/0032 

LNGFIRE3), IBR approved for 

§ 193.2057(a). 

(3) GTI–04/0049 ‘‘LNG Vapor 

Dispersion Prediction with the 

DEGADIS 2.1: Dense Gas Dispersion 

Model for LNG Vapor Dispersion,’’ 

April 2004, (GTI–04/0049), IBR 

approved for § 193.2059(a). 

(g) National Fire Protection 

Association (NFPA), 1 Batterymarch 

Park, Quincy, MA, 02169 phone: 617– 

984–7275, Web site: http://

www.nfpa.org/. 

(1) NFPA–59A (2001), ‘‘Standard for 

the Production, Storage, and Handling 

of Liquefied Natural Gas (LNG),’’ 

(NFPA–59A–2001), IBR approved for 

§§ 193.2019(a), 193.2051, 193.2057, 

193.2059 introductory text and (c), 

193.2101(a), 193.2301, 193.2303, 

193.2401, 193.2521, 193.2639(a), and 

193.2801. 

(2) NFPA 59A (2006), ‘‘Standard for 

the Production, Storage, and Handling 

of Liquefied Natural Gas (LNG),’’ 2006 

edition, approved August 18, 2005, 

(NFPA–59A–2006), IBR approved for 

§§ 193.2101(b) and 193.2321(b). 

§ 193.2059 [Amended] 

■ 36. Amend § 193.2059 as follows: 

■ a. Amend the introductory text by 

removing the term ‘‘NFPA 59A’’ and 

adding in its place the term ‘‘NFPA– 

59A–2001’’. 

■ b. Amend paragraph (a) by removing 

the words ‘‘Gas Research Institute report 

GRI–89/0242 (incorporated by reference, 

see § 193.2013), ‘‘LNG Vapor Dispersion 

Prediction with the DEGADIS Dense Gas 

Dispersion Model’’’’ and adding, in its 

place, ‘‘GTI–04/0049, ‘‘LNG Vapor 

Dispersion Prediction with the 

DEGADIS 2.1 Dense Gas Dispersion 

Model’’’’ (incorporated by reference, see 

§ 193.2013)’’. 

■ c. Amend paragraph (c) by removing 

the term ‘‘NFPA 59A’’ and adding in its 

place the term ‘‘NFPA–59A–2001’’. 

§ 193.2067 [Amended] 

■ 37. Amend § 193.2067 paragraph 

(b)(1) by removing the term ‘‘ASCE/SEI 

7–05’’ and adding in its place the term 

‘‘ASCE/SEI 7’’. 

§ 193.2101 [Amended] 

■ 38. Revise § 193.2101 to read as 

follows: 

§ 193.2101 Scope. 

(a) Each LNG facility designed after 

March 31, 2000 must comply with the 

requirements of this part and of NFPA– 

59A–2001 (incorporated by reference, 

see § 193.2013). If there is a conflict 

between this Part and NFPA–59A–2001, 

the requirements in this part prevail. 

(b) Each stationary LNG storage tank 

must comply with Section 7.2.2 of 

NFPA–59A–2006 (incorporated by 

reference, see § 193.2013) for seismic 

design of field fabricated tanks. All 

other LNG storage tanks must comply 

with API Std–620 (incorporated by 

reference, see § 193.2013) for seismic 

design. 

■ 39. In § 193.2321, revise paragraphs 

(a), (b)(1), and (b)(2) to read as follows: 

§ 193.2321 Nondestructive tests. 

(a) The butt welds in metal shells of 

storage tanks with internal design 

pressure above 15 psig must be 

nondestructively examined in 

accordance with the ASME Boiler and 

Pressure Vessel Code (BPVC) (Section 

VIII, Division 1)(incorporated by 

reference, see § 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 

nondestructively examined in 

accordance with the ASME BPVC 

(Section VIII, Division 1). 

(b) * * * 

(1) Section 7.3.1.2 of NFPA Std–59A– 

2006, (incorporated by reference, see 

§ 193. 2012); 

(2) Appendices C and Q of API Std 

620, (incorporated by reference, see 

§ 193.2013); 

* * * * * 

§ 193.2513 [Amended] 

■ 40. Amend § 193.2513, paragraphs 

(b)(1) and (c)(5), by removing the words 

‘‘AGA ‘‘Purging Principles and 

Practice’’’’ and adding, in its place, 

‘‘Purging Principles and Practices 

(incorporated by reference, see 

§ 193.2013)’’. 

§ 193.2517 [Amended] 

■ 41. Amend § 193.2517 by removing 

the words ‘‘AGA ‘‘Purging Principles 

and Practice’’’’ and adding, in its place, 

‘‘Purging Principles and Practices 

(incorporated by reference, see 

§ 193.2013)’’. 

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184 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

§ 193.2615 [Amended] 

■ 42. Amend § 193.2615(a) by removing 

the words ‘‘AGA ‘‘Purging Principles 

and Practice’’’’ and adding, in its place, 

‘‘Purging Principles and Practices 

(incorporated by reference, see 

§ 193.2013)’’. 

PART 195—TRANSPORTATION OF 

HAZARDOUS LIQUIDS BY PIPELINE 

■ 43. 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. 

§§ 195.5, 195.406 [Amended] 

■ 44. Amend 49 CFR part 195 by 

removing the term ‘‘ASME B31.8’’ and 

adding in its place the term ‘‘ASME/

ANSI B31.8 (incorporated by reference, 

see § 195.3)’’ in the following sections. 

■ a. Section 195.5 paragraph (a)(1)(i); 

■ b. Section 195.406 paragraph (a)(1)(i). 

■ 45. Section 195.3 is revised to read as 

follows: 

§ 195.3 What documents are incorporated 

by reference partly or wholly in this part? 

(a) This part prescribes standards, or 

portions thereof, incorporated by 

reference into this part with the 

approval of the Director of the Federal 

Register in 5 U.S.C. 552(a) and 1 CFR 

part 51. The materials listed in this 

section have the full force of law. To 

enforce any edition other than that 

specified in this section, PHMSA must 

publish a notice of change in the 

Federal Register. 

(1) Availability of standards 

incorporated by reference. All of the 

materials incorporated by reference are 

available for inspection from several 

sources, including the following: 

(i) The Office of Pipeline Safety, 

Pipeline and Hazardous Materials Safety 

Administration, 1200 New Jersey 

Avenue SE., Washington, DC 20590. For 

more information contact 202–366–4046 

or go to the PHMSA Web site at: http:// 

www.phmsa.dot.gov/pipeline/regs. 

(ii) The National Archives and 

Records Administration (NARA). For 

information on the availability of this 

material at NARA, call 202–741–6030 or 

go to the NARA Web site at: http://

www.archives.gov/federal_register/

code_of_federal_regulations/ibr_

locations.html. 

(iii) Copies of standards incorporated 

by reference in this part can also be 

purchased from the respective 

standards-developing organization at 

the addresses provided in the 

centralized IBR section below. 

(b) American Petroleum Institute 

(API), 1220 L Street NW., Washington, 

DC 20005, and phone: 202–682–8000, 

Web site: http://api.org/. 

(1) API Publication 2026, ‘‘Safe 

Access/Egress Involving Floating Roofs 

of Storage Tanks in Petroleum Service,’’ 

2nd edition, April 1998 (reaffirmed June 

2006) (API Pub 2026), IBR approved for 

§ 195.405(b). 

(2) API Recommended Practice 5L1, 

‘‘Recommended Practice for Railroad 

Transportation of Line Pipe,’’ 7th 

edition, September 2009, (API RP 5L1), 

IBR approved for § 195.207(a). 

(3) API Recommended Practice 5LT, 

‘‘Recommended Practice for Truck 

Transportation of Line Pipe,’’ First 

edition, March 12, 2012, (API RP 5LT), 

IBR approved for § 195.207(c). 

(4) API Recommended Practice 5LW, 

‘‘Recommended Practice Transportation 

of Line Pipe on Barges and Marine 

Vessels,’’ 3rd edition, September 2009, 

(API RP 5LW), IBR approved for 

§ 195.207(b). 

(5) ANSI/API Recommended Practice 

651, ‘‘Cathodic Protection of 

Aboveground Petroleum Storage 

Tanks,’’ 3rd edition, January 2007, 

(ANSI/API RP 651), IBR approved for 

§§ 195.565 and 195.573(d). 

(6) ANSI/API Recommended Practice 

652, ‘‘Linings of Aboveground 

Petroleum Storage Tank Bottoms,’’ 3rd 

edition, October 2005, (API RP 652), IBR 

approved for § 195.579(d). 

(7) API Recommended Practice 1130, 

‘‘Computational Pipeline Monitoring for 

Liquids: Pipeline Segment,’’ 3rd edition, 

September 2007, (API RP 1130), IBR 

approved for §§ 195.134 and 195.444. 

(8) API Recommended Practice 1162, 

‘‘Public Awareness Programs for 

Pipeline Operators,’’ 1st edition, 

December 2003, (API RP 1162), IBR 

approved for § 195.440(a), (b), and (c). 

(9) API Recommended Practice 1165, 

‘‘Recommended Practice for Pipeline 

SCADA Displays,’’ First edition, January 

2007, (API RP 1165), IBR approved for 

§ 195.446(c). 

(10) API Recommended Practice 1168, 

‘‘Pipeline Control Room Management,’’ 

First edition, September 2008, (API RP 

1168), IBR approved for § 195.446(c) 

and (f). 

(11) API Recommended Practice 2003, 

‘‘Protection against Ignitions Arising out 

of Static, Lightning, and Stray 

Currents,’’ 7th edition, January 2008, 

(API RP 2003), IBR approved for 

§ 195.405(a). 

(12) API Recommended Practice 2350, 

‘‘Overfill Protection for Storage Tanks in 

Petroleum Facilities,’’ 3rd edition, 

January 2005, (API RP 2350), IBR 

approved for § 195.428(c). 

(13) API Specification 5L, 

‘‘Specification for Line Pipe,’’ 45th 

edition, effective July 1, 2013, (ANSI/

API Spec 5L), IBR approved for 

§ 195.106(b) and (e). 

(14) ANSI/API Specification 6D, 

‘‘Specification for Pipeline Valves,’’ 

23rd edition, effective October 1, 2008, 

(including Errata 1 (June 2008), Errata 2 

(November 2008), Errata 3 (February 

2009), Errata 4 (April 2010), Errata 5 

(November 2010), and Errata 6 (August 

2011); Addendum 1 (October 2009), 

Addendum 2 (August 2011), and 

Addendum 3 (October 2012)); (ANSI/

API Spec 6D), IBR approved for 

§ 195.116(d). 

(15) API Specification 12F, 

‘‘Specification for Shop Welded Tanks 

for Storage of Production Liquids,’’ 12th 

edition, October 2008, effective April 1, 

2009, (API Spec 12F), IBR approved for 

§§ 195.132(b); 195.205(b); 195.264(b) 

and (e); 195.307(a); 195.565; 195.579(d). 

(16) API Standard 510, ‘‘Pressure 

Vessel Inspection Code: In-Service 

Inspection, Rating, Repair, and 

Alteration,’’ 9th edition, June 2006, (API 

Std 510), IBR approved for 

§§ 195.205(b); 195.432(c). 

(17) API Standard 620, ‘‘Design and 

Construction of Large, Welded, LowPressure Storage Tanks,’’ 11th edition 

February 2008 (including addendum 1 

(March 2009), addendum 2 (August 

2010), and addendum 3 (March 2012)), 

(API Std 620), IBR approved for 

§§ 195.132(b); 195.205(b); 195.264(b) 

and (e); 195.307(b); 195.565, 195.579(d). 

(18) API Standard 650, ‘‘Welded Steel 

Tanks for Oil Storage,’’ 11th edition, 

June 2007, effective February 1, 2012, 

(including addendum 1 (November 

2008), addendum 2 (November 2009), 

addendum 3 (August 2011), and errata 

(October 2011)), (API Std 650), IBR 

approved for §§ 195.132(b); 195.205(b); 

195.264(b), (e); 195.307(c) and (d); 

195.565; 195.579(d). 

(19) API Standard 653, ‘‘Tank 

Inspection, Repair, Alteration, and 

Reconstruction,’’ 3rd edition, December 

2001, (including addendum 1 

(September 2003), addendum 2 

(November 2005), addendum 3 

(February 2008), and errata (April 

2008)), (API Std 653), IBR approved for 

§§ 195.205(b), 195.307(d), and 

195.432(b). 

(20) API Standard 1104, ‘‘Welding of 

Pipelines and Related Facilities,’’ 20th 

edition, October 2005, (including errata/ 

addendum (July 2007) and errata 2 

(2008), (API Std 1104)), IBR approved 

for §§ 195.214(a), 195.222(a) and (b), 

195.228(b). 

(21) ANSI/API Standard 2000, 

‘‘Venting Atmospheric and Lowpressure Storage Tanks,’’ 6th edition, 

November 2009, (ANSI/API Std 2000), 

IBR approved for § 195.264(e). 

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Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 185 

(22) API Standard 2510, ‘‘Design and 

Construction of LPG Installations,’’ 8th 

edition, 2001, (API Std 2510), IBR 

approved for §§ 195.132(b), 195.205(b), 

195.264 (b), (e); 195.307 (e), 195.428 (c); 

and 195.432 (c). 

(c) ASME International (ASME), Two 

Park Avenue, New York, NY 10016, 

800–843–2763 (U.S/Canada), Web site: 

http://www.asme.org/. 

(1) ASME/ANSI B16.9–2007, 

‘‘Factory-Made Wrought Buttwelding 

Fittings,’’ December 7, 2007, (ASME/

ANSI B16.9), IBR approved for 

§ 195.118(a). 

(2) ASME/ANSI B31G–1991 

(Reaffirmed 2004), ‘‘Manual for 

Determining the Remaining Strength of 

Corroded Pipelines,’’ 2004, (ASME/

ANSI B31G), IBR approved for 

§§ 195.452(h); and 195.587. 

(3) ASME/ANSI B31.4–2006, 

‘‘Pipeline Transportation Systems for 

Liquid Hydrocarbons and Other 

Liquids’’ October 20, 2006, (ASME/

ANSI B31.4), IBR approved for 

§§ 195.110(a); 195.452(h). 

(4) ASME/ANSI B31.8–2007, ‘‘Gas 

Transmission and Distribution Piping 

Systems,’’ November 30, 2007, (ASME/ 

ANSI B31.8), IBR approved for 

§§ 195.5(a) and 195.406(a). 

(5) ASME Boiler & Pressure Vessel 

Code, Section VIII, Division 1, ‘‘Rules 

for Construction of Pressure Vessels,’’ 

2007 edition, July 1, 2007, (ASME 

BPVC, Section VIII, Division 1), IBR 

approved for §§ 195.124 and 195.307(e). 

(6) ASME Boiler & Pressure Vessel 

Code, Section VIII, Division 2, 

‘‘Alternate Rules, Rules for Construction 

of Pressure Vessels,’’ 2007 edition, July 

1, 2007, (ASME BPVC, Section VIII, 

Division 2), IBR approved for 

§ 195.307(e). 

(7) ASME Boiler & Pressure Vessel 

Code, Section IX: ‘‘Qualification 

Standard for Welding and Brazing 

Procedures, Welders, Brazers, and 

Welding and Brazing Operators,’’ 2007 

edition, July 1, 2007, (ASME BPVC, 

Section IX), IBR approved for 

§ 195.222(a). 

(d) American Society for Testing and 

Materials (ASTM), 100 Barr Harbor 

Drive, P.O. Box C700, West 

Conshohocken, PA 119428, phone: 610– 

832–9585, Web site: http://

www.astm.org/. 

(1) ASTM A53/A53M–10, ‘‘Standard 

Specification for Pipe, Steel, Black and 

Hot-Dipped, Zinc-Coated, Welded and 

Seamless,’’ approved October 1, 2010, 

(ASTM A53/A53M), IBR approved for 

§ 195.106(e). 

(2) ASTM A106/A106M–10, 

‘‘Standard Specification for Seamless 

Carbon Steel Pipe for High-Temperature 

Service,’’ approved April 1, 2010, 

(ASTM A106/A106M), IBR approved for 

§ 195.106(e). 

(3) ASTM A333/A333M–11, 

‘‘Standard Specification for Seamless 

and Welded Steel Pipe for LowTemperature Service,’’ approved April 

1, 2011, (ASTM A333/A333M), IBR 

approved for § 195.106(e). 

(4) ASTM A381–96 (Reapproved 

2005), ‘‘Standard Specification for 

Metal-Arc Welded Steel Pipe for Use 

with High-Pressure Transmission 

Systems,’’ approved October 1, 2005, 

(ASTM A381), IBR approved for 

§ 195.106(e). 

(5) ASTM A671/A671M–10, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for 

Atmospheric and Lower Temperatures,’’ 

approved April 1, 2010, (ASTM A671/ 

A671M), IBR approved for § 195.106(e). 

(6) ASTM A672/A672M–09, 

‘‘Standard Specification for ElectricFusion-Welded Steel Pipe for HighPressure Service at Moderate 

Temperatures,’’ approved October 1, 

2009, (ASTM A672/A672M), IBR 

approved for § 195.106(e). 

(7) ASTM A691/A691M–09, 

‘‘Standard Specification for Carbon and 

Alloy Steel Pipe, Electric-FusionWelded for High-Pressure Service at 

High Temperatures,’’ approved October 

1, 2009, (ASTM A691), IBR approved for 

§ 195.106(e). 

(e) Manufacturers Standardization 

Society of the Valve and Fittings 

Industry, Inc. (MSS), 127 Park St. NE., 

Vienna, VA 22180, phone: 703–281– 

6613, Web site: http://www.mss-hq 

.org/. 

(1) MSS SP–75–2008 Standard 

Practice, ‘‘Specification for High-Test, 

Wrought, Butt-Welding Fittings,’’ 2008 

edition, (MSS SP 75), IBR approved for 

§ 195.118(a). 

(2) [Reserved] 

(f) NACE International (NACE), 1440 

South Creek Drive, Houston, TX 77084, 

phone: 281–228–6223 or 800–797–6223, 

Web site: http://www.nace.org/

Publications/. 

(1) NACE SP0169–2007, Standard 

Practice, ‘‘Control of External Corrosion 

on Underground or Submerged Metallic 

Piping Systems’’ reaffirmed March 15, 

2007, (NACE SP0169), IBR approved for 

§§ 195.571 and 195.573(a). 

(2) ANSI/NACE SP0502–2010, 

Standard Practice, ‘‘Pipeline External 

Corrosion Direct Assessment 

Methodology,’’ June 24, 2010, (NACE 

SP0502), IBR approved for § 195.588(b). 

(g) National Fire Protection 

Association (NFPA), 1 Batterymarch 

Park, Quincy, MA 02169, phone: 617– 

984–7275, Web site: http://

www.nfpa.org/. 

(1) NFPA–30 (2012), ‘‘Flammable and 

Combustible Liquids Code,’’ including 

Errata 30–12–1 (9/27/11), and Errata 30– 

12–2 (11/14/11), 2012 edition, copyright 

2011, (NFPA–30), IBR approved for 

§ 195.264(b). 

(2) [Reserved] 

(h) Pipeline Research Council 

International, Inc. (PRCI), c/o Technical 

Toolboxes, 3801 Kirby Drive, Suite 520, 

P.O. Box 980550, Houston, TX 77098, 

phone: 713–630–0505, toll free: 866– 

866–6766, Web site: http://

www.ttoolboxes.com/. 

(1) AGA Pipeline Research 

Committee, Project PR–3–805 ‘‘A 

Modified Criterion for Evaluating the 

Remaining Strength of Corroded Pipe,’’ 

December 22, 1989, (PR–3–805 

(RSTRING)). IBR approved for 

§§ 195.452(h); 195.587. 

(2) [Reserved] 

■ 46. Amend § 195.106 as follows: 

■ a. In paragraph (b)(1)(i), remove the 

term ‘‘API Specification 5L’’ and add in 

its place the term ‘‘ANSI/API Spec 5L 

(incorporated by reference, see 

§ 195.3)’’. 

■ b. Revise paragraph (e) to read as 

follows: 

§ 195.106 Internal design pressure. 

* * * * * 

(e)(1) The seam joint factor used in 

paragraph (a) of this section is 

determined in accordance with the 

following standards incorporated by 

reference (see § 195.3): 

Specification Pipe class Seam joint 

factor 

ASTM A53/A53M ................................................ Seamless ............................................................................................................... 1.00 

Electric resistance welded ..................................................................................... 1.00 

Furnace lap welded ............................................................................................... 0.80 

Furnace butt welded .............................................................................................. 0.60 

ASTM A106/A106M ............................................ Seamless ............................................................................................................... 1.00 

ASTM A333/A333M ............................................ Seamless ............................................................................................................... 1.00 

Welded ................................................................................................................... 1.00 

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186 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

Specification Pipe class Seam joint 

factor 

ASTM A381 ......................................................... Double submerged arc welded .............................................................................. 1.00 

ASTM A671/A671M ............................................ Electric-fusion-welded ............................................................................................ 1.00 

ASTM A672/A672M ............................................ Electric-fusion-welded ............................................................................................ 1.00 

ASTM A691/A691M ............................................ Electric-fusion-welded ............................................................................................ 1.00 

ANSI/API Spec 5L ............................................... Seamless ............................................................................................................... 1.00 

Electric resistance welded ..................................................................................... 1.00 

Electric flash welded .............................................................................................. 1.00 

Submerged arc welded .......................................................................................... 1.00 

Furnace lap welded ............................................................................................... 0.80 

Furnace butt welded .............................................................................................. 0.60 

(2) The seam joint factor for pipe that 

is not covered by this paragraph must be 

approved by the Administrator. 

§ 195.116 [Amended] 

■ 47. Amend § 195.116 (d) by removing 

the term ‘‘API Standard 6D’’ and adding 

in its place the term ‘‘ANSI/API Spec 

6D’’. 

§ 195.118 [Amended] 

■ 48. Amend § 195.118 paragraph (a) by 

removing the term ‘‘ASME/ANSI B16.9 

or MSS Standard Practice SP–75’’ and 

adding in its place the term ‘‘ASME/

ANSI B16.9 or MSS SP–75 

(incorporated by reference, see 

§ 195.3)’’. 

■ 49. Section 195.124 is revised to read 

as follows: 

§ 195.124 Closures. 

Each closure to be installed in a 

pipeline system must comply with the 

2007 ASME Boiler and Pressure Vessel 

Code (BPVC) (Section VIII, Division 1) 

(incorporated by reference, see § 195.3) 

and must have pressure and 

temperature ratings at least equal to 

those of the pipe to which the closure 

is attached. 

§ 195.132 [Amended] 

■ 50. Amend § 195.132 as follows: 

■ a. Amend paragraph (b)(1) by 

removing the term ‘‘API Specification 

12F’’ and adding in its place ‘‘API Spec 

12F (incorporated by reference, see 

§ 195.3)’’. 

■ b. Amend paragraph (b)(2) by 

removing the term ‘‘API Standard 620’’ 

and adding in its place ‘‘API Std 620 

(incorporated by reference, see 

§ 195.3)’’. 

■ c. Amend paragraph (b)(3) by 

removing the term ‘‘API Standard 650’’ 

and adding in its place ‘‘API Std 650 

(incorporated by reference, see 

§ 195.3)’’. 

■ d. Amend paragraph (b)(4) by 

removing the term ‘‘API Standard 2510’’ 

and adding in its place ‘‘API Std 2510 

(incorporated by reference, see 

§ 195.3)’’. 

§ 195.134 [Amended] 

■ 51. Amend § 195.134 by removing the 

term ‘‘API 1130’’ and adding in its place 

‘‘API RP 1130 (incorporated by 

reference, see § 195.3)’’ the first instance 

and ‘‘API RP 1130’’ the second instance. 

■ 52. In 195.205, paragraph (b) is 

revised to read as follows: 

§ 195.205 Repair, alteration and 

reconstruction of aboveground breakout 

tanks that have been in service. 

* * * * * 

(b) After October 2, 2000, compliance 

with paragraph (a) of this section 

requires the following: 

(1) For tanks designed for 

approximate atmospheric pressure, 

constructed of carbon and low alloy 

steel, welded or riveted, and nonrefrigerated; and for tanks built to API 

Std 650 (incorporated by reference, see 

§ 195.3) or its predecessor Standard 12C; 

repair, alteration; and reconstruction 

must be in accordance with API Std 653 

(except section 6.4.3) (incorporated by 

reference, see § 195.3). 

(2) For tanks built to API Spec 12F 

(incorporated by reference, see § 195.3) 

or API Std 620 (incorporated by 

reference, see § 195.3), repair, alteration, 

and reconstruction must be in 

accordance with the design, welding, 

examination, and material requirements 

of those respective standards. 

(3) For high-pressure tanks built to 

API Std 2510 (incorporated by 

reference, see § 195.3), repairs, 

alterations, and reconstruction must be 

in accordance with API Std 510 

(incorporated by reference, see § 195.3). 

■ 53. Amend § 195.207 as follows: 

■ a. In paragraph (a), remove the term 

‘‘API Recommended Practice 5L1’’ and 

add in its place the term ‘‘API RP 5L1.’’ 

■ b. In paragraph (b), remove the term 

‘‘API Recommended Practice 5LW’’ and 

add in its place the term ‘‘API RP 5LW.’’ 

■ c. Add a new paragraph (c) to read as 

set forth below: 

§ 195.207 Transportation of pipe. 

* * * * * 

(c) Truck. 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 truck unless the 

transportation is performed in 

accordance with API RP 5LT 

(incorporated by reference, see § 195.3). 

■ 54. In § 195.214, revise paragraph (a) 

to read as follows: 

§ 195.214 Welding procedures. 

(a) Welding must be performed by a 

qualified welder in accordance with 

welding procedures qualified under 

Section 5 of API Std 1104 or Section IX 

of the ASME Boiler and Pressure Vessel 

Code (ASME BPVC) (incorporated by 

reference, see § 195.3). The quality of 

the test welds used to qualify the 

welding procedure shall be determined 

by destructive testing. 

* * * * * 

■ 55. In § 195.222, revise the section 

heading and paragraphs (a) and (b)(2) to 

read as follows: 

§ 195.222 Welders: Qualification of 

welders and welding operators. 

(a) Each welder or welding operator 

must be qualified in accordance with 

section 6 or 12 of API Std 1104 

(incorporated by reference, see § 195.3) 

or with Section IX of ASME Boiler and 

Pressure Vessel Code (BPVC) 

(incorporated by reference, see § 195.3), 

except that a welder qualified under an 

earlier edition than listed in § 195.3 may 

weld but may not re-qualify under that 

earlier edition. 

(b) * * * 

(2) Had one weld tested and found 

acceptable under section 9 or Appendix 

A of API Std 1104 (incorporated by 

reference, see § 195.3). 

§ 195.228 [Amended] 

■ 56. Amend § 195.228(b) by removing 

the term ‘‘API 1104’’ and adding in its 

place the term ‘‘API Std 1104’’ in two 

locations. 

■ 57. In § 195.264, paragraphs (b)(1) and 

(2) and (e)(1) through (4) are revised to 

read as follows: 

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Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 187 

§ 195.264 Impoundment, protection 

against entry, normal/emergency venting or 

pressure/vacuum relief, for aboveground 

breakout tanks. 

* * * * * 

(b) * * * 

(1) For tanks built to API Spec 12F, 

API Std 620, and others (such as API 

Std 650 (or its predecessor Standard 

12C)), the installation of impoundment 

must be in accordance with the 

following sections of NFPA–30 

(incorporated by reference, see § 195.3); 

(i) Impoundment around a breakout 

tank must be installed in accordance 

with section 22.11.2; and 

(ii) Impoundment by drainage to a 

remote impounding area must be 

installed in accordance with section 

22.11.1. 

(2) For tanks built to API Std 2510 

(incorporated by reference, see § 195.3), 

the installation of impoundment must 

be in accordance with section 5 or 11 of 

API Std 2510. 

* * * * * 

(e) * * * 

(1) Normal/emergency relief venting 

installed on atmospheric pressure tanks 

built to API Spec 12F must be in 

accordance with section 4 and 

Appendices B and C of API Spec 12F 

(incorporated by reference, see § 195.3). 

(2) Normal/emergency relief venting 

installed on atmospheric pressure tanks 

(such as those built to API Std 650 or 

its predecessor Standard 12C) must be 

in accordance with API Std 2000 

(incorporated by reference, see § 195.3). 

(3) Pressure-relieving and emergency 

vacuum-relieving devices installed on 

low-pressure tanks built to API Std 620 

must be in accordance with Section 9 of 

API Std 620 (incorporated by reference, 

see § 195.3) and its references to the 

normal and emergency venting 

requirements in API Std 2000 

(incorporated by reference, see § 195.3). 

(4) Pressure and vacuum-relieving 

devices installed on high-pressure tanks 

built to API Std 2510 must be in 

accordance with sections 7 or 11 of API 

Std 2510 (incorporated by reference, see 

§ 195.3). 

■ 58. Section 195.307 is revised to read 

as follows: 

§ 195.307 Pressure testing aboveground 

breakout tanks. 

(a) For aboveground breakout tanks 

built to API Spec 12F (incorporated by 

reference, see § 195.3) and first placed 

in service after October 2, 2000, 

pneumatic testing must be performed in 

accordance with section 5.3 of API Spec 

12 F. 

(b) For aboveground breakout tanks 

built to API Std 620 (incorporated by 

reference, see § 195.3) and first placed 

in service after October 2, 2000, 

hydrostatic and pneumatic testing must 

be performed in accordance with 

section 7.18 of API Std 620. 

(c) For aboveground breakout tanks 

built to API Std 650 (incorporated by 

reference, see § 195.3) and first placed 

in service after October 2, 2000, testing 

must be performed in accordance with 

Sections 7.3.5 and 7.3.6 of API Standard 

650. 

(d) For aboveground atmospheric 

pressure breakout tanks constructed of 

carbon and low alloy steel, welded or 

riveted, and non-refrigerated; and tanks 

that are returned to service after October 

2, 2000, and are built to API Std 650 

(incorporated by reference, see § 195.3) 

or its predecessor Standard 12C; the 

necessity for the hydrostatic testing of 

repair, alteration, and reconstruction is 

covered in Section 12.3 of API Std 653. 

(e) For aboveground breakout tanks 

built to API Std 2510 (incorporated by 

reference, see § 195.3) and first placed 

in service after October 2, 2000, 

pressure testing must be performed in 

accordance with 2007 ASME Boiler and 

Pressure Vessel Code (BPVC) (Section 

VIII, Division 1 or 2). 

■ 59. Section 195.405 is revised to read 

as follows: 

§ 195.405 Protection against ignitions and 

safe access/egress involving floating roofs. 

(a) After October 2, 2000, protection 

provided against ignitions arising out of 

static electricity, lightning, and stray 

currents during operation and 

maintenance activities involving 

aboveground breakout tanks must be in 

accordance with API RP 2003 

(incorporated by reference, see § 195.3), 

unless the operator notes in the 

procedural manual (§ 195.402(c)) why 

compliance with all or certain 

provisions of API RP 2003 is not 

necessary for the safety of a particular 

breakout tank. 

(b) The hazards associated with 

access/egress onto floating roofs of inservice aboveground breakout tanks to 

perform inspection, service, 

maintenance, or repair activities (other 

than specified general considerations, 

specified routine tasks or entering tanks 

removed from service for cleaning) are 

addressed in API Pub 2026 

(incorporated by reference, see § 195.3). 

After October 2, 2000, the operator must 

review and consider the potentially 

hazardous conditions, safety practices, 

and procedures in API Pub 2026 for 

inclusion in the procedure manual 

(§ 195.402(c)). 

■ 60. In § 195.432, revise paragraphs (b) 

and (c) to read as follows: 

§ 195.432 Inspection of in-service breakout 

tanks. 

* * * * * 

(b) Each operator must inspect the 

physical integrity of in-service 

atmospheric and low-pressure steel 

above-ground breakout tanks according 

to API Std 653 (except section 6.4.3, 

Alternative Internal Inspection Interval) 

(incorporated by reference, see § 195.3). 

However, if structural conditions 

prevent access to the tank bottom, its 

integrity may be assessed according to a 

plan included in the operations and 

maintenance manual under 

§ 195.402(c)(3). The risk-based internal 

inspection procedures in API Std 653, 

section 6.4.3 cannot be used to 

determine the internal inspection 

interval. 

(1) Operators who established internal 

inspection intervals based on risk-based 

inspection procedures prior to March 6, 

2015 must re-establish internal 

inspection intervals based on API Std 

653, section 6.4.2 (incorporated by 

reference, see § 195.3). 

(i) If the internal inspection interval 

was determined by the prior risk-based 

inspection procedure using API Std 653, 

section 6.4.3 and the resulting 

calculation exceeded 20 years, and it 

has been more than 20 years since an 

internal inspection was performed, the 

operator must complete a new internal 

inspection in accordance with 

§ 195.432(b)(1) by January 5, 2017. 

(ii) If the internal inspection interval 

was determined by the prior risk-based 

inspection procedure using API Std 653, 

section 6.4.3 and the resulting 

calculation was less than or equal to 20 

years, and the time since the most 

recent internal inspection exceeds the 

re-established inspection interval in 

accordance with § 195.432(b)(1), the 

operator must complete a new internal 

inspection by January 5, 2017. 

(iii) If the internal inspection interval 

was not based upon current engineering 

and operational information (i.e., actual 

corrosion rate of floor plates, actual 

remaining thickness of the floor plates, 

etc.), the operator must complete a new 

internal inspection by January 5, 2017 

and re-establish a new internal 

inspection interval in accordance with 

§ 195.432(b)(1). 

(2) [Reserved] 

(c) Each operator must inspect the 

physical integrity of in-service steel 

aboveground breakout tanks built to API 

Std 2510 (incorporated by reference, see 

§ 195.3) according to section 6 of API 

Std 510 (incorporated by reference, see 

§ 195.3). 

* * * * * 

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188 Federal Register / Vol. 80, No. 2 / Monday, January 5, 2015 / Rules and Regulations 

§ 195.444 [Amended] 

■ 61. Amend § 195.444 by removing the 

term ‘‘API 1130’’ and adding in its place 

‘‘API RP 1130 (incorporated by 

reference, see § 195.3).’’ 

■ 62. In § 195.452, revise paragraphs 

(h)(4)(i)(B), (h)(4)(iii)(D), and paragraph 

(l)(1) to read as follows: 

§ 195.452 Pipeline integrity management in 

high consequence areas. 

* * * * * 

(h) * * * 

(4) * * * 

(i) * * * 

(B) A calculation of the remaining 

strength of the pipe shows a predicted 

burst pressure less than the established 

maximum operating pressure at the 

location of the anomaly. Suitable 

remaining strength calculation methods 

include, but are not limited to, ASME/ 

ANSI B31G (incorporated by reference, 

see § 195.3) and PRCI PR–3–805 (R– 

STRENG) (incorporated by reference, 

see § 195.3). 

* * * * * 

(iii) * * * 

(D) A calculation of the remaining 

strength of the pipe shows an operating 

pressure that is less than the current 

established maximum operating 

pressure at the location of the anomaly. 

Suitable remaining strength calculation 

methods include, but are not limited to, 

ASME/ANSI B31G and PRCI PR–3–805 

(R–STRENG). 

* * * * * 

(l) What records must an operator 

keep to demonstrate compliance?—(1) 

An operator must maintain, for the 

useful life of the pipeline, records that 

demonstrate compliance with the 

requirements of this subpart. At a 

minimum, an operator must maintain 

the following records for review during 

an inspection: 

(i) A written integrity management 

program in accordance with paragraph 

(b) of this section. 

(ii) Documents to support the 

decisions and analyses, including any 

modifications, justifications, deviations 

and determinations made, variances, 

and actions taken, to implement and 

evaluate each element of the integrity 

management program listed in 

paragraph (f) of this section. 

* * * * * 

■ 63. Section 195.565 is revised to read 

as follows: 

§ 195.565 How do I install cathodic 

protection on breakout tanks? 

After October 2, 2000, when you 

install cathodic protection under 

§ 195.563(a) to protect the bottom of an 

aboveground breakout tank of more than 

500 barrels 79.49m3 capacity built to 

API Spec 12F (incorporated by 

reference, see § 195.3), API Std 620 

(incorporated by reference, see § 195.3), 

API Std 650 (incorporated by reference, 

see § 195.3), or API Std 650’s 

predecessor, Standard 12C, you must 

install the system in accordance with 

ANSI/API RP 651 (incorporated by 

reference, see § 195.3). However, you 

don’t need to comply with ANSI/API RP 

651 when installing any tank for which 

you note in the corrosion control 

procedures established under 

§ 195.402(c)(3) why complying with all 

or certain provisions of ANSI/API RP 

651 is not necessary for the safety of the 

tank. 

■ 64. In § 195.573, revise paragraph (d) 

to read as follows: 

§ 195.573 What must I do to monitor 

external corrosion control? 

* * * * * 

(d) Breakout tanks. You must inspect 

each cathodic protection system used to 

control corrosion on the bottom of an 

aboveground breakout tank to ensure 

that operation and maintenance of the 

system are in accordance with API RP 

651 (incorporated by reference, see 

§ 195.3). However, this inspection is not 

required if you note in the corrosion 

control procedures established under 

§ 195.402(c)(3) why complying with all 

or certain operation and maintenance 

provisions of API RP 651 is not 

necessary for the safety of the tank. 

* * * * * 

■ 65. In § 195.579, revise paragraph (d) 

to read as follows: 

§ 195.579 What must I do to mitigate 

internal corrosion? 

* * * * * 

(d) Breakout tanks. After October 2, 

2000, when you install a tank bottom 

lining in an aboveground breakout tank 

built to API Spec 12F (incorporated by 

reference, see § 195.3), API Std 620 

(incorporated by reference, see § 195.3), 

API Std 650 (incorporated by reference, 

see § 195.3), or API Std 650’s 

predecessor, Standard 12C, you must 

install the lining in accordance with API 

RP 652 (incorporated by reference, see 

§ 195.3). However, you don’t need to 

comply with API RP 652 when 

installing any tank for which you note 

in the corrosion control procedures 

established under § 195.402(c)(3) why 

compliance with all or certain 

provisions of API RP 652 is not 

necessary for the safety of the tank. 

■ 66. Section 195.587 is revised to read 

as follows: 

§ 195.587 What methods are available to 

determine the strength of corroded pipe? 

Under § 195.585, you may use the 

procedure in ASME/ANSI B31G 

(incorporated by reference, see § 195.3) 

or in PRCI PR–3–805 (R–STRENG) 

(incorporated by reference, see § 195.3) 

to determine the strength of corroded 

pipe based on actual remaining wall 

thickness. These procedures apply to 

corroded regions that do not penetrate 

the pipe wall, subject to the limitations 

set out in the respective procedures. 

PART 198—REGULATIONS FOR 

GRANTS TO AID STATE PIPELINE 

SAFETY PROGRAMS 

■ 67. The authority citation for Part 198 

continues to read as follows: 

Authority: 49 U.S.C. 60105, 60106, 60114, 

and 49 CFR 1.53. 

§ 198.37 [Amended] 

■ 68. Amend paragraph (f) by removing 

the phrase ‘‘§ 192.614 (b)(4) through 

(b)(6)’’ and adding in its place 

‘‘§ 192.614 (c)(4) through (c)(6).’’ 

PART 199—DRUG AND ALCOHOL 

TESTING 

■ 69. The authority citation for Part 199 

continues to read as follows: 

Authority: 49 U.S.C. 5103, 60102, 60104, 

60108, 60117, and 60118; and 49 CFR 1.53. 

§ 199.111 [Removed and Reserved] 

■ 70. Remove and reserve § 199.111. 

Issued in Washington, DC, on December 

18, 2014, under authority delegated in 49 

CFR 1.97(a). 

Timothy P. Butters, 

Acting Administrator. 

[FR Doc. 2014–30336 Filed 1–2–15; 8:45 am] 

BILLING CODE 4910–60–P 

DEPARTMENT OF COMMERCE 

National Oceanic and Atmospheric 

Administration 

50 CFR Part 679 

[Docket No. 131021878–4158–02] 

RIN 0648–XD693 

Fisheries of the Exclusive Economic 

Zone Off Alaska; Inseason Adjustment 

to the 2015 Bering Sea and Aleutian 

Islands Pollock, Atka Mackerel, and 

Pacific Cod Total Allowable Catch 

Amounts 

AGENCY: National Marine Fisheries 

Service (NMFS), National Oceanic and 

Atmospheric Administration (NOAA), 

Commerce. 

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