PHMSA = Pipelines and Hazardous. RITA = Research and Innovative Technologies Administration

Transcription

1 Arkansas Gas Pipeline Safety Seminar June 20-21, 21, 2007 Arkansas Public Service Commission PHMSA T&Q

2 Wayne St. Germain Pipeline Safety Specialist Phone (405) Live Person (405) Direct Line Fax (405)

3 DOT Reorganization PHMSA = Pipelines and Hazardous Materials Administration RITA = Research and Innovative Technologies Administration

4 DOT Reorganization NTSB FMCSA FRA MARAD FAA DOT NHTSA RITA PHMSA FTA TSI HMT OPS

5 PHMSA Pipeline Safety Strategic Plans & Assessment Technology & Standards Monitoring State Programs Compliance

6 PHMSA s Mission Statement To ensure the safe, reliable, and environmentally sound operation of the nation s pipeline transportation system.

7 PHMSA Training & Qualification (T & Q) Division Provides Training for: State and Federal Pipeline Inspectors (Courses in OKC) Industry Personnel via Seminars Arkansas

8 Pipeline Jurisdictions Pipeline A Interstate (Federal) Intrastate (State) Pipeline B

9 State Programs Section State Adopted: p Certifications Pipeline Safety Regulations as a minimum Enforcement Authority Pipeline Safety Law

10 Compliance Section Operator shall: Comply with Applicable Safety Standards Prepare and Follow an O&M Plan Maintain Records Required by the Safety Standards Pipeline Safety Law

11 Pipeline Safety Law The Pipeline Safety Improvement Act of 2002 Signed Into Law December, 2002 Reauthorization Bill in 2006

12 PHMSA Reauthorization Pipeline Safety Improvement Act Expired in 2006 Pipeline Inspection, Protection, Enforcement, and Safety Act of 2006 (PIPES) - John Jacobi OPS/CATS

13 Final Rule issued March 15, 2006 Amendment Gas Gathering Line Definition Definitions under the rule are slight modifications of the definitions contained in API RP 80, Guidelines for the Definition of Onshore Gas Gathering Lines: Higher safety standards for high risk onshore gathering lines Relaxed standards on low risk onshore gathering lines

14 Final Rule issued April 23, 2007 Design and Construction Standards To Reduce Internal Corrosion in Gas Transmission Pipelines Requires operators to use design and construction features in new and replaced gas transmission pipelines to reduce the risk of internal corrosion. This final rule takes effect May 23, 2007

15 Final Rule issued April 23, 2007 Design and Construction Standards To Reduce Internal Corrosion in Gas Transmission Pipelines The design and construction features required by this rule will reduce the risk of internal corrosion and related pipeline failures by reducing the potential for accumulation of liquids and facilitating operation and maintenance practices that address internal corrosion.

16 Final Rule issued April 23, 2007 Amendment Design and Construction Standards To Reduce Internal Corrosion in Gas Transmission Pipelines General requirements. * * * * * (b) The design and installation of pipeline components and facilities must meet applicable requirements for corrosion control found in subpart I of this part.

17 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (a) Design and construction. Except as provided in paragraph (b) of this section, each new transmission line and each replacement of line pipe, valve, fitting, or other line component in a transmission i line must have features incorporated into its design and construction to reduce the risk of internal corrosion.

18 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (a) (continued) At a minimum, unless it is impracticable or unnecessary to do so, each new transmission line or replacement of line pipe, valve, fitting, or other line component in a transmission line must:

19 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (a) (continued) (1) Be configured to reduce the risk that liquids will collect in the line; (2) Have effective liquid removal features whenever the configuration would allow liquids to collect; and

20 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (a) (continued) (3) Allow use of devices for monitoring internal corrosion at locations with significant potential for internal corrosion.

21 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (b) Exceptions to applicability. The design and construction requirements of paragraph (a) of this section do not apply to the following:

22 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (b) Exceptions to applicability (continued) (1) Offshore pipeline; p and (2) Pipeline installed or line pipe, valve, fitting or other line component replaced before May 23, 2007.

23 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (c) Change to existing transmission line. When an operator changes the configuration of a transmission line, the operator must evaluate the impact of the change on internal corrosion risk to the downstream portion of an existing onshore transmission line and provide for removal of liquids and monitoring of internal corrosion as appropriate.

24 Final Rule issued April 23, 2007 Continued Internal corrosion control: Design and construction of transmission line. (d) Records. An operator must maintain records demonstrating compliance with this section. Provided the records show why incorporating design features addressing paragraph (a)(1), (a)(2), or (a)(3) of this section is impracticable or unnecessary, an operator may fulfill this requirement through written procedures supported by as-built drawings or other construction records.

25 Operator Qualification PHMSA Concept Paper Regulatory Add construction tasks to operation and maintenance tasks Add some specificity in training Add some specificity in intervals for reevaluation Non-Regulatory Publish clarifications Of Note: PHMSA does not intend to immediately incorporate ASME B31.Q into regulations.

26 PHMSA Advisory Bulletin on Excavation Activities To: Owners and Operators of Natural Gas and Hazardous Liquid Pipeline Systems Excavation is a covered task. Review the adequacy of covered tasks involving line locating, one-call notifications and inspection of excavation activities. Each employee and operator must be qualified to perform that task. Reference: ADB

27 NTSB SCADA Study Recommendations 1. Review and audit alarms 2. Train controllers with simulator or non- computerized simulations to recognize abnormal operating conditions 3. Follow API RP 1165 (when available) for graphics on SCADA screen 4. Change accident reporting to include controller fatigue 5. Install computer based leak detection on all liquid lines (unless engineering analysis deems unnecessary).

28 New Requirements for the Pipeline Operator Final Public Awareness Rule effective June 20, CFR and titled Public Awareness Programs must follow the guidance in API RP 1162, First Edition, December 2003 ( RP 1162 ) Baseline and Supplemental (aka Enhanced) Programs

29 Applicability of the Public Awareness Rule Gas Transmission & Hazardous Liquids Gas Distribution ib ti Communication about Liquefied Natural Gas (LNG) and Propane/Air peak-shaving facilities are not part of the public awareness program required by Gas Gathering

30 Public Awareness Rule Plans for 2006 Frequently Asked Questions posted to Beginning on or before July 2006, Operators should: Implement RP 1162-compliant public awareness programs Submit written program to Clearinghouse and State agency with jurisdiction, as directed in Advisory Bulletin

31 Public Awareness Rule Plans for 2006 Advisory Bulletin published June 16, 2006: Must Submit Written Public Awareness to PHSA Clearinghouse between 8/8/06 and 10/8/06 Not Applicable to Master Meters or Small LP Operators Also N/A to Small Intrastate Operators in CT, DC, Illinois, MD, MT, SD, VA, WY Must Have Operator ID No. and Other Pertinent Info (see details in bulletin)

32 Public Awareness Rule Plans for 2006 Advisory Bulletin published June 16, 2006: E-filing Recommended Check OPS Website after 8/8/06 for LINK Mailing Computer Disk (or Written Copy) also Allowed: Public Awareness Program Clearinghouse PHMSA th St. SW Washington, DC 20590

33 Final Rule issued June 9, 2006 & February 2, 2007 (corrections) Amendment Update of Regulatory References to Technical Standards Revised to update to latest editions on many industry and association technical standards Mainly PRCI, ASTM, ASME, MSS, NFPA, PPI, NACE, GTI Docket No. PHMSA

34 Final Rule issued June 9, 2006 & February 2, 2007 (corrections) Amendment Update of Regulatory References to Technical Standards Revised to update to latest editions on many industry and association technical standards Mainly PRCI, ASTM, ASME, MSS, NFPA, PPI, NACE, GTI Docket No. PHMSA

35 Miscellaneous Gas IMP protocols revised and new FAQ s added API RP 1166, Excavation Monitoring and Observation, issued Regulation of rural crude gathering pipelines under consideration based on size, stress level, and ability to affect an HCA

36 Grant of Waiver; Kinder Morgan Louisiana Pipeline, LLC Federal Register: April 19, 2007 (Volume 72, Number 75) The Pipeline and Hazardous Materials Safety Administration (PHMSA) is granting Kinder Morgan Louisiana Pipeline, LLC (KMLP) a waiver of compliance from the Federal pipeline safety regulations for a new natural gas transmission pipeline. The regulations establish the maximum stress level and overpressure protection limits for natural gas pipelines.

37 Background Information MAOP

38 MAOP "Maximum Allowable Operating Pressure" means the maximum pressure at which a pipeline or segment of a pipeline may be opeated operated under this Part. at.

39 Subpart L : MAOP ~ MAOP: Steel or Plastic Pipelines ~ MAOP: High-Pressure Distribution Systems ~ MAOP: Low-Pressure Distribution Systems

40 All Steel or Plastic Pipelines MAOP cannot exceed Lowest of the following: Design Pressure of Weakest Element De-rated Test Pressure MOP during the 5 years preceding applicable date Maximum Safe Pressure determined by the Operator

41 ~ Transmission Lowest of the following: Design Test Pressure MOP during the 5 years preceding applicable date Maximum Safe Pressure determined by the Operator

42 Design of Pipe and Components Pipe For Steel For Plastic Components Manufacturers Rating

43 Design Formula for Steel Pipe P = (2St/D) x F x E x T P = Design Pressure, psig S = Yield Strength, psi D = Pipe Outside Diameter, inches t = Pipe Nominal Wall Thickness, inches F = Design factor E = Longitudinal joint factor T = Temperature derating factor

44 Example Pipe Specifications ~ Transmission API 5L Grade B 8" nom. dia " w.t.

45 Barlow's Formula: P=2St/D P=(2)(35,000)(.322)/8.625 P = 2613# Equivalent Pressure at 100% SMYS

46 : Design Factor (F) for Steel Pipe Class location Design factor (F)

47 Grant of Waiver; Kinder Morgan Louisiana Pipeline, LLC Federal Register: April 19, 2007 (Volume 72, Number 75) This waiver allows KMLP to operate a new natural gas transmission pipeline at a maximum allowable operating pressure (MAOP) corresponding to a pipe stress level up to 80 percent of the steel pipe's specified minimum yield strength (SMYS) in rural areas along the pipeline route.

48 Grant of Waiver; Kinder Morgan Louisiana Pipeline, LLC Federal Register: April 19, 2007 (Volume 72, Number 75) PHMSA previously issued three waivers allowing operators to operate natural gas transmission pipelines above 72 percent SMYS. Granted with conditions that require operators to meet certain specified safety criteria. The safety criteria were developed from information received from the public meeting, industry best practices and internal research.

49 Pipeline Safety Websites ops.dot.gov primis.phmsa.dot.gov phmsa

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51 PHMSA Accomplishments in Pipeline Safety Improved Public Confidence Positive reviews from Congress, NTSB, GAO, & Inspector General during recent Congressional Hearings Better informed public and stakeholder community

52 Challenges for PHMSA in Pipeline Safety Rebuilding Public Confidence after Bellingham and Carlsbad Accidents Public Perception of Unresponsiveness Pressures to Perform (Congress, NTSB, IG) Perception of Being Too Close to Industry Growing Economy Strain to Meet Energy Demand/Pipeline Capacity Zero-Risk Society Growing Stakeholder Community (Agencies, Advocates, Local Communities, Citizen Groups)

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