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High Consequence Areas & Pipeline Assessment Intervals –Is there a
need for change?Terry Boss
Sr. VP Environment Safety and OperationsInterstate Natural Gas Association of
America
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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
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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
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4
Market and Population is Dispersed
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The Natural Gas Industry Marketers
272,500 Gas Wells
Producers• Majors• Independents
Gathering
Storage
Commercial
Residential
Industrial &Utilities
1200 Distributors
Storage
30 MajorInterstatePipelines
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Interstate Natural Gas Pipelines
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More Interstate Natural Gas Pipeline Informationwww.ingaa.org
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Managing Public RiskNatural Gas Transmission Pipeline Safety Development
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Pipeline Safety - Layers of Protection Example
OPS49 CFR192/5
ASMEB31.4/8
NACERP-0169 & RP-0502
APIRP-1163
Close Internal SurveyDirect Current Voltage Gradient
HydrotestingInline Inspection
Integrity Management
Regulations
Codes
Standards
Practices
Programs
External Corrosion Threat
SCC
ConstInternal
Mfg
Research & Development
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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
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Example “High Consequence Area”
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C-FER HCA determined by Pres. & Diameter
0100200300400500600700800900
1,0001,1001,2001,3001,4001,5001,6001,700
0 250 500 750 1,000 1,250 1,500 1,750 2,000 2,250 2,500
Maximum Operating Pressure (psig)
Dis
tan
ce (
ft)
3"
4"
6"
8"
10"
12"
16"
20"
24"
30"
36"
42"
Worst Case Consequence Analysis
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r = 1009 ft.
Constant Consequence Concept
660 ft.
660 ft.
Pipeline diameter “d” (inches) = 36”
MAOP 1650 psig: PIR = 1000 ft
PIR = 0.69 pd2
Pipeline diameter “d” (inches) = 30”
MAOP 1000 psig: PIR = 655 ft
Pipeline diameter “d” (inches) = 18”
MAOP 600 psig: PIR = 304 ft
20 houses within circle
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Pictorial of a High Consequence Area for Natural Gas Overlaid on the Class Location System
660 ft
30” Pipeline
1010 psig
HousesClass 3
HCA
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Number of Significant Incidents
Number of Fatalities
Number of Injuries
Property Damage
Results of the IMP Program
(PHMSA) Carlsbad
Hurricanes
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Ongoing Performance Metrics -PHMSA
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INGAA Foundation Report
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Probability of Failure
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Types Failures
Static Anomalies Detrimental Non - Detrimental
Time Independent Defects Excavation Damage Weather Terrorist
Time Dependent Defects Corrosion Cracking
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Manage Time Dependent Defects
Manage Time Dependent Effects Inline Inspection Pressure Test Direct Assessment Other Approved Methods
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Integrity Assessment Technology Split
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GAO Report (Sept 2006)
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Timeline For IMP
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Interaction of Baseline and Continuing Assessments
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Condition of gas transmission pipelines are better than original public
perception
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GAO concludes that 7 year reassessment period is conservative
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Requesting Flexibility in IMP Program Schedule
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Public Workshop to gather comments on Special Permit and Criteria Discussion for 7-year ReassessmentsLocation: Arlington, VirginiaJan 18, 2008
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Congressional Testimony - March 2008
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Number of Reportable Incidents
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Number of Immediate Repairs
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Number of Scheduled Repairs
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Ongoing Initiatives to Improve Performance
• Tools• Processes• Procedures• Implementation
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Cased Pipeline Integrity Assessment Workshop
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Anomaly Assessment and Repair Workshop - October 22, 2008
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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
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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=5296519d7e818110VgnVCM1000009ed07898RCRD&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-eaq-hrg.031208.PIPE.shtml