High Consequence Areas & Pipeline Assessment Intervals Is

High Consequence Areas & Pipeline Assessment Intervals Is

High Consequence Areas & Pipeline Assessment Intervals Is there a need for change? Terry Boss Sr. VP Environment Safety and Operations Interstate Natural Gas Association of America Outline

Natural Gas and Transportation Management of Public Risk Results of the IMP Program Requesting Flexibility in IMP Program Schedule Ongoing Initiatives to Improve Performance Natural Gas and Transportation

Primarily Methane Hydrogen with some Carbon Swamp Gas Lower Density of Energy Gaseous

Locations of Supply is Diverse Locations of Market is Diverse Transportation by Pipelines is Most Feasible Bridge Fuel Primary Risk is Fire Lighter than Air Limited Ignition Range Heat Radiation based on Quantity Market and Population is Dispersed

4 The Natural Gas Industry Marketers Storage Commercial Residential Producers Majors

Independents 272,500 Gas Wells Industrial & Utilities Gathering Storage

30 Major Interstate Pipelines 1200 Distributors Interstate Natural Gas Pipelines More Interstate Natural Gas Pipeline Information www.ingaa.org

Managing Public Risk Natural Gas Transmission Pipeline Safety Development Pipeline Safety - Layers of Protection Example Regulations OPS 49 CFR 192/5 Codes

ASME B31.4/8 Standards NACE RP-0169 & RP-0502 API RP-1163 Close Internal Survey Direct Current Voltage Gradient Hydrotesting

Inline Inspection Mfg Practices Programs Const Integrity Management

Internal SCC Research & Development External Corrosion Threat Natural Gas Transmission Pipeline Risk Management biased by Population Density Design

Design Classes Materials Strength of Pipe Construction Construction Techniques

Operation Operating pressures and Practices Inspection Frequency and Type of Inspection Maintenance Example

High Consequence Area 11 Worst Case Consequence Analysis Distance (ft) C-FER HCA determined by Pres. & Diameter 1,700 1,600

1,500 1,400 1,300 1,200 1,100 1,000 900 800 700 600 500

400 300 200 100 0 3" 4" 6" 8" 10"

12" 16" 20" 24" 30" 36" 42" 0 250

500 750 1,000 1,250 1,500 1,750 2,000 2,250 2,500 Maximum Operating Pressure (psig) Constant Consequence Concept Pipeline diameter d (inches) = 36

Pipeline diameter d (inches) = 18 MAOP 1650 psig: PIR = 1000 ft MAOP 600 psig: PIR = 304 ft Pipeline diameter d (inches) = 30 MAOP 1000 psig: PIR = 655 ft 660 ft. r = 1009 ft.

660 ft. PIR = 0.69 pd2 20 houses within circle Pictorial of a High Consequence Area for Natural Gas Overlaid on the Class Location System Class 3

30 Pipeline 1010 psig Houses 660 ft HCA

14 Results of the IMP Program (PHMSA) Carlsbad Number of Significant Incidents

Number of Fatalities Number of Injuries Property Damage Hurricanes

Ongoing Performance Metrics -PHMSA INGAA Foundation Report Probability of Failure Types Failures Static Anomalies Detrimental Non - Detrimental

Time Independent Defects Excavation Damage Weather Terrorist Time Dependent Defects Corrosion Cracking Manage Time Dependent Defects Manage Time Dependent Effects

Inline Inspection Pressure Test Direct Assessment Other Approved Methods Integrity Assessment Technology Split

GAO Report (Sept 2006) Timeline For IMP Interaction of Baseline and Continuing Assessments Condition of gas transmission pipelines are better than original public perception

GAO concludes that 7 year reassessment period is conservative Requesting Flexibility in IMP Program Schedule Public Workshop to gather comments on Special Permit and Criteria Discussion for 7year Reassessments Location: Arlington, Virginia Jan 18, 2008

Congressional Testimony - March 2008 Number of Reportable Incidents Number of Immediate Repairs Number of Scheduled Repairs Ongoing Initiatives to Improve Performance

Tools Processes Procedures Implementation Cased Pipeline Integrity Assessment Workshop

Anomaly Assessment and Repair Workshop - October 22, 2008 Conclusions Natural Gas is a Very Important Energy Source Flexible and Readily Available Bridge Fuel for Climate Change Energy Security Public Risk Can and Is Being Managed

Flexibility in the IMP Program is Very Desirable Commitment to Ongoing Improvement Background Material

COMPARISON OF INTEGRITY MANAGEMENT ASSESSMENT TECHNIQUES FOR NATURAL GAS TRANSMISSION PIPELINES www.ingaa.org F-2007-09 NATURAL GAS PIPELINE SAFETY Risk-Based Standards Should Allow Operators to Better Tailor Reassessments to Pipeline Threats www.gao.gov GAO-06-945 Integrity Management Plan Metrics http://primis.phmsa.dot.gov/gasimp/PerformanceMeasures.htm PHMSA Workshops

Public Workshop to gather comments on Special Permit and Criteria Discussion for 7-year Reassessments http://www.phmsa.dot.gov/portal/site/PHMSA/menuitem.ebdc7a8a7e39f2e55cf2031050248a0c/? vgnextoid=4aeb8defc8de6110VgnVCM1000001ecb7898RCRD&vgnextchannel=5296519d7e818110VgnVCM1 000009ed07898RCRD&vgnextfmt=print

Cased Pipeline Integrity Assessment Workshop https://primis.phmsa.dot.gov/meetings/MtgHome.mtg? mtg=54 Anomaly Assessment and Repair Workshop https://primis.phmsa.dot.gov/meetings/MtgHome.mtg?mtg=55 Congressional Hearing The Pipeline Inspection, Protection, Enforcement, and Safety Act of 2006: Implementation Review and Discussion of Safety Reassessment Intervals for Natural Gas Pipelines; Subcommittee on Energy and Air Quality Wednesday, March 12, 2008 http://energycommerce.house.gov/cmte_mtgs/110-eaqhrg.031208.PIPE.shtml

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