Guided Wave UT Inspection of Cased Crossings

1
(No Transcript)
2
Regulatory UpdateAN SGA WEB CONFERENCEMarch 7,
2008 900 AM to 1030 AM ET
3
Regulatory Update March 7, 2008 930 AM to
1130 AM CT
Mike Grubb SGA [phone] mgrubb_at_souther
ngas.org
Natalie Corey CTN [phone]
coreyn_at_bellsouth.net
4
(No Transcript)
5
MODERATOR Beverly Melchisedech, CenterPoint
Energy (beverley.melchisedech_at_centerpointenergy.co
m)
6

• Public Awareness
• Presenter Blaine Keener, PHMSA (CATS)
  (blaine.keener_at_dot.gov)
• Update from the Feb. 20, 2008 public meeting
• Audit (Clearinghouse - status)

7

U. S. Department of Transportation
Pipeline and Hazardous Materials Safety
Administration
www.dot.gov
8
Summary of Clearinghouse Results
PHMSA Public Meeting onPublic Awareness
Programsfor Pipeline OperatorsFebruary 20,
2008Houston, TXPresented by Blaine Keener

9
Clearinghouse Advisory Bulletin

• Published June 16, 2006 and requested submission
  of Written Programs by October 8, 2006
• 8 States decided to conduct independent Written
  Program reviews
• CT, DC, IL, MD, MT, SD, VA, WY
• Review Criteria for the Clearinghouse were
  developed jointly by National Association of
  Pipeline Safety Representatives (NAPSR) PHMSA
• Central Clearinghouse conducted an initial review
  of Written Programs with feedback to the
  jurisdictional pipeline safety agency(ies)

10
Clearinghouse Submittals

• Required information
• OpID
• System Types Regions / States of Operation
• Documents comprising the Written Public Awareness
  Program
• Submittal confirmation e-mails sent to operator
  and jurisdictional agency(ies)
• All submittal information stored in Public
  Awareness Program Database (PAPD)

11
Which Operators Required to Submit?

• Gas Distribution (GD), except for Master Meter
  Operators and certain Propane Operators
• All Gas Transmission (GT) Hazardous Liquids
  (HL) Operators
• All Gathering (Gath) Operators
• PHMSA tracked submissions against the set of
  operators who submitted CY 2005 Annual Reports

12
ProgramsSubmitted

• 1,568 Programs covering 1,961 Operators
• Vast majority of Programs covered systems
  jurisdictional to State Pipeline Safety Programs
• 1,082 Programs for GD All systems in AK and
  some in CA VA jurisdictional to OPS
• 568 Programs for GT / HL 136 Programs covered
  systems jurisdictional to OPS
• 144 Programs for Gathering

13
ClearinghouseReview

• GD Program reviews began 10-2006
• GT/HL Gath Program reviews began 1-2007
• Operators were sending Awareness Materials to
  stakeholders during the Clearinghouse review of
  the Written Programs
• Awareness Materials being sent to stakeholders
  were not reviewed by the Clearinghouse
• Clearinghouse closed 10-2007

14
Review Criteria

• RP 1162 Structure
• Management Support Personnel Roles
• Implementation Audit
• Effectiveness Evaluation
• Communication for all Audiences
• Methods
• Frequencies
• Messages
• Supplemental Elements

15
Results fromthe Clearinghouse

• Aspects of Written Program that differed from
  recommendations in RP 1162 recorded as a
  Deviation in the database
• Supplemental elements implemented recorded
• Jurisdictional agency(ies) e-mailed summary of
  Deviations and Supplementals implemented
• OPS CATS Managers working with Operators to
  resolve Deviations

16
DeviationStatistics
17
Gas DistributionDeviations

• 41 Damage Prevention messages to
  Affected Public
• 36 Pipeline purpose reliability to
  Affected Public
• 32 Awareness of hazards and preventive
  measures undertaken to Affected Public
• 30 How will messages be delivered to
  Affected Public

18
Gas DistributionDeviations (cont)

• 34 How will messages be delivered to
  Excavators
• 32 How will messages be delivered to
  Emergency Officials
• 18 How will messages be delivered to
  customers of the gas company
• 17 Frequency of messages to customers
  of the gas company

19
Gas DistributionDeviations (cont)

• 4 Frequency of messages to Emergency
  Officials
• 5 Frequency of messages to Local
  Public Officials
• 6 Frequency of messages to Excavators
• 7 Emergency preparedness communications
  to Emergency Officials
• 7 Frequency of messages to Affected Public

20
Gas Trans Haz LiqDeviations

• Nuisance Deviations generated by Poorly
  Structured Questions on Pipeline Location
  Information
• Do baseline awareness materials to Affected
  Public, Emergency Officials Local Public
  Officials include Pipeline location information
  (description of the purpose of pipeline markers
  and the information on them)?
• Pipeline location information recommended
  inTable 2-1 of API RP 1162 to be part of
  theWritten Program
• Description of the purpose of pipeline markers
  and the information on them to be included
  inAwareness Materials

21
Gas Trans Haz LiqDeviations (cont)

• 70 Process procedure to determine
  implementation of Supplemental Elements in
  High Consequence Areas (HCA)
• HCA supplemental enhancements, as described in RP
  1162, meet the ASME B31.8S external
  communications requirements for GT Integrity
  Management Programs
• 36 of GT/HL Programs implement Supplemental
  Elements in response to HCAs

22
Gas Trans Haz Liq Deviations (cont)

• 54 Availability of list of pipeline operators
  through NPMS to Affected Public
• 37 Pipeline purpose and reliability to
  Affected Public
• 35 Awareness of hazards and prevention
  measures undertaken to Affected Public
• 38 How will messages be delivered to
  Emergency Officials

23
Gas Trans Haz Liq Deviations (cont)

• 34 Pipeline purpose and reliability to
  Excavators
• 34 One-call requirements to Local
  Public Officials
• 34 Member of all appropriate One Call
  Centers
• 33 Awareness of hazards and prevention
  measures undertaken to Excavators

24
Gas Trans Haz Liq Deviations (cont)

• 13 Frequency of messages to Emergency
  Officials Local Public Officials
• 14 Frequency of messages to Affected Public
• 16 One-call requirements to Excavators
• 16 Leak recognition and response to
  Affected Public
• 16 Emergency Preparedness Communications
  to Emergency Officials

25
Gathering Deviations

• 88 Copies of materials provided to Affected
  Public and Emergency Officials to
  Local Public Officials
• 68 General location and purpose of gathering
  pipeline to Excavators
• 60 Specific description of products
  transported and any potential special
  hazards to Emergency Officials

26
Gathering Deviations (cont)

• 52 General location and purpose of gathering
  pipeline to Local Public Officials
• 51 Gathering pipeline location and purpose
  to Emergency Officials
• 50 Prevention measures undertaken to
  Excavators
• 44 How will messages be delivered to
  Emergency Officials

27
Gathering Deviations (cont)

• 15 Frequency of messages to Local
  Public Officials
• 17 Frequency of messages to Excavators
• 19 Frequency of messages to Emergency
  Officials
• 20 Frequency of messages to Affected
  Public

28
All ProgramsDeviations

• 82 Process procedure to determine
  implementation of Supplemental Elements in
  response to Third-Party Damage
• Significant Incidents Caused by Excavation Damage
  from 2002-2006
• HL 14 Incidents, 63 Fatalities, 16 Injuries
• GT 13 Incidents, 80 Fatalities, 23 Injuries
• GD 37 Incidents, 28 Fatalities, 32 Injuries
• 17 implemented Supplemental Elements in response
  to Third-Party Damage

29
All ProgramsDeviations

• 82 Process procedure to determine
  implementation of Supplemental Elements
  in response to factors other than Third-Party
  Damage and HCAs
• 55 Effectiveness Evaluation every 4 years
• 51 Management Statement of Support
• 50 Annual audit of Program to ensure
  developed and implemented according to
  the guidelines in RP 1162

30
Summary of Summary

• New aspects of public awareness resulted in the
  highest percentage of deviations
• All Programs supplemental elements,
  effectiveness evaluation, implementation audit
• GD GT/HL messages to Affected Public
• Gathering pipeline location and purpose to
  various audiences

31
Revising MessagesNPMSwww.npms.phmsa.dot.gov

• April 2007 changes to the National Pipeline
  Mapping System (NPMS)
• Public access to maps within a zip code,
  including attributes such as operator name,
  product, and operator contact
• Local Public Officials and Emergency Officials
  can get electronic data layer AND add this layer
  to their own GIS
• Operator messages about NPMS should be modified
  to reflect new capabilities

32
Revising Messages811www.call811.com

• National Call Before You Dig number went live
  May 1, 2007
• Market research demonstrates homeowners often
  dont make the call
• CGA DIRT report of CY 2004 and 2005 shows 31 of
  damages and near misses have a root cause of No
  Notification to One-Call Center
• 811 should have a prominent role in Public
  Awareness Programs.

33
Revising MessagesPipeline Emergencies
On-Linewww.pipelineemergencies.com

• National Association of State Fire Marshals
  (NASFM) first responder training curriculum
  completed January 2005
• On-line version scheduled for release March 2008
• Seven sessions
• Designed for pipeline safety awareness and as
  promotional piece for full curriculum
• Operators encouraged to provide the on-line
  version link to Emergency Officials

34
Questions ???
Summary of Clearinghouse Results

• blaine.keener_at_dot.gov
• 202-366-0970

35

U. S. Department of Transportation
Pipeline and Hazardous Materials Safety
Administration
www.dot.gov
36

• Distribution Integrity Management Programs
• Presenter Mike Beatty, South Carolina Electric
  Gas - a SCANA Company (mdbeatty_at_scana.com)
• Member SGA DIMP Interest Group Committee
• Regulatory update
• What can operators be doing now?
• Resources
• GPTC document
• SGA discussion document
• Phase 1 ReportSGA
• SGA DIMP Round Table - July 23/24, 2008 -
  Atlanta

37
Distribution Integrity Management Program

• Blaine Keener - Pipeline Hazardous Materials
  Safety Administration (PHMSA)
• Phil Bennett - American Gas Association (AGA)

38
Expected Timeline

• Proposed NPRM - April, 2008
• Trade Association Meetings - March to June, 2008
  
• Comments Due on NPRM- June 30, 2008
• Final Rule - April, 2009
• Operators integrity plans developed by- April,
  2010
• Operators implement integrity plans - October,
  2010

39
What Can We Be Doing Now?
40
Excess Flow Valves

• Congress passed PIPES Act in 2006 mandating the
  installation of EFVs as of June 1, 2008.
• After June 1, 2008, EFVs must be installed
• New/replacement services lines serving single
  residential customers
• Operating pressure gt 10 psig
• If contamination will not prevent proper
  operation
• If EFV in size required is commercially available
• Rule may not be promulgated by June 1, 2008

41
Excess Flow Valves contd

• EFV Considerations
• Implementation
• Timeline
• Training
• OM Manual revisions
• Application / Sizing Considerations
• Location
• Testing / Purging / Resetting
• Turning on / off Meters
• Record keeping
• Service Cards
• CIS
• GIS
• Leak Reports
• Customer Load increases

42
The anticipated 7 key elements
Distribution pipeline operators, regardless of
size, shall implement a system-wide integrity
management program including seven key elements,
namely that each operator

• Develop and implement a written integrity
  management plan. Between April 2009 and April
  2010
• Know your infrastructure.
• Identify threats, both existing and of potential
  future importance.
• Assess and prioritize risks.
• Identify and implement appropriate measures to
  mitigate risks.
• Measure performance, monitor results, and
  evaluate the effectiveness of its programs,
  making changes where needed.
• Periodically report a limited set of performance
  measures to regulator(s).

43
Threats

• The categories of threats to be considered should
  include the eight threats identified by PHMSA in
  the Annual Distribution Report
• PHMSA Form 7100.1-1 as Cause of Leaks in Part
  C
• Excavation
• Other outside force
• Natural Forces
• Incorrect Operations
• Equipment
• Corrosion
• Material or welds (construction)
• Other

44
Threats contd

• Threats are
• Damages
• Failures
• Damages and Failures may or may not result in a
  leak.
• Leak Management is a key part of addressing
  Threats

45
Threats contd

• Mechanical Damage by 1st, 2nd, or 3rd Party is
  the Major Threat.
• Consider
• Hits per 1000 locates.
• Break this down into hits with tickets without
  tickets
• Adding/gathering root cause analysis
• Locator QA/QC
• Enforcement and Damage Recovery
• Develop metrics to evaluate performance

46
Consider other supporting programs

• Internal programs
• 1162 Public Awareness programs
• Operator Qualifications programs
• Locating (In-House or Contractor)
• GIS or Maps/Facility
• External Programs
• One call
• Common Ground Alliance

47
SGA - Assisting its members

• Once a proposed DIMP rule is published in the
  Federal Register
• Develop/Implement a Web Conference for the
  purpose of educating members on key concepts of
  the Rule. Depending on interest, this may be a
  face to face meeting/workshop.
• Prepare and file consensus comments if directed
  by the Distribution Operating Section Managing
  Committee.
• Once a final Rule is published, or sufficient
  information is known about the Rule
• Sponsor a face-to-face meeting when rule is
  issued to educate membership and provide a forum
  for the exchange of ideas and concepts.
• Develop/Implement a survey to define current
  practices
• Develop/Implement Web Conference on the 7
  elements
• Measure interest in the development of a
  compliance framework document. Members might
  collaborate by committee (offer subject matter
  experts), or seek outside resources (share
  expenses for this service).
• Support the Guidance process of GPTC and
  American Public Gas Association (APGA)

48
Resources

• Gas Piping Technology Committee (GTPC) Guidance
  Document
• APGA Plan SHRIMP Simple, Handy, Risk-based,
  Integrity, Management, Plan
• SGA DIMP Interest Group web page
• http//www.southerngas.org/DISTRIBUTION-OPERATION
  S/DistributionIntegrityManagementProgramsDIMP.htm
  
• On this page you will find
• SGA DIMP Discussion Document
• Phase 1 Report
• Information on the SGA DIMP Round Table scheduled
  July 23/24, 2008 at the Distribution Conference
  in Atlanta

49
Resources

• Please contact any member of the steering
  committee for further information
• Mike Beatty, Manager, Engineering Construction,
  South Carolina Electric Gas Company
• Craig Hoeferlin, Vice President, Operations,
  Laclede Gas Company
• Phillip Murdock, Director, Asset Management,
  Atmos Energy
• David Cicoria, Manager, Systems Operations,
  Columbia Gas of Virginia, a Nisource Company
• SGA contacts
• Mike Grubb, Staff Executive, SGA
• Fraser Farmer, Staff Executive, SGA

50

• Texas Railroad Commission - Notice of Proposed
  Rulemaking
• Presenter Phil Bennett, AGA (pbennett_at_aga.org)
• Risk-based leak inspection program
• Leak grading and repair
• Mandatory removal and replacement program

51
Operator Qualifications Presenter Mike
Burkhart, Nicor (mburkha_at_nicor.com)
52
Plastic Pipe Presenter Richard Sanders, PHMSA
(Richard.Sanders_at_dot.gov)
53

• Gas Control
• Presenter Karen Butler, Community Assistance and
  Technical Services (Karen.Butler_at_dot.gov)
• Prevention Through People
• Recommended Practices
• Control Room Fatigue

54

U. S. Department of Transportation
Pipeline and Hazardous Materials Safety
Administration
55
Control Room Management Community Assistance
and Technical Services Karen Butler 2008

56
(No Transcript)
57

• THANK YOU!

58
Project Drivers

• Advisory Bulletins
• Accident/Incident/SRCR/Complaints/Inquiries
• Pipeline Safety Improvement Act of 2002
• Study Control Room operations to enhance
  pipeline safety
• Provide Report to Congress
• NTSB
• SCADA Safety Study and Recommendations
• Most Wanted Fatigue/Hours of Service
• PIPES Act of 2006 (Sections 12, 19, 20)
• Establish human factors management plan
• Reduce risks associated with human factors
• Program to assure safe operation of pipelines
• NTSB Recommendations on Displays, Alarms and
  Training
• Accident/Incident form changes on Fatigue by
  Dec. 31, 2007
• Issue regulations by June 1, 2008

59
Enterprise Approach Key Information Resources

• Cross-section of Pipeline Operators
• Pilot Operators
• Comparative Industries
• Focus Group
• Public Workshops
• Technical Publications
• Pipeline Modeling SCADA Vendors
• Established Research
• NTSB
• PHMSA data

60
Pilot Project Field Survey Topics

• Operator System Overview, Control Room Tour
• Process Steps for Controller Development and
  Qualification
• Controller Operating Logistics and Experience
  Base
• OQ Implementation Resources
• Task Identification
• Candidate Selection
• Initial Training
• Computer Modeling and Operations Support Systems
• Qualification
• Ongoing Controller Performance Monitoring
• Re-Qualification
• Qualification Revocation and Restoration

• Root Cause Analysis and Feedback
• Global Metrics
• SCADA Controller Operations Interface
• SCADA System Design/Configuration
• Alarm Configuration, Management and Operations
• Security and Access Control
• Controller Interview
• Control Management Interview
• Management of Change
• Ancillary Procedures, Systems and Work
  Environment
• Administrative Support and Records Management
• Upcoming Systems and Procedure Changes

61
Field Survey Visits Including Pilot Operators

• Operator Type Mileage
• ----------------------------------- ----------- --
  -----------------
• Pacific Gas Electric GT/LDC 6300 / 38000
• Buckeye Partners HL 4500
• Colonial Pipeline HL 5571
• Gulf South Pipeline GT 7500
• Puget Sound Energy LDC 12000
• Brenham Mun. Gas LDC 208
• Olympic Pipeline HL 400
• Koch Pipeline HL 8500
• Atlanta Gas Light LDC 30000
• Enbridge Pipelines HL/GT 50000
• New Jersey Natural GT/LDC 208 / 6000
• IEC/Penn Power Light HL/GT 86
• Philadelphia Gas Works LDC 3000
• Magellan HL 10220
• ChevronTexaco HL 8139
• Duke Energy Gas GT 11816
• Alyeska Pipeline HL 800

62
Comparative Industries

• FAA, Air Traffic Controllers and Pilots
• FRA, Railroad Engineers and Dispatchers
• Nuclear, Plant Operators
• Electric Energy Grid, Network Operations
• OSHA and EPA Procedures

63
(No Transcript)
64
Enhancement Areas

• Roles Responsibilities
• Shift Change
• Fatigue Awareness Mitigation
• SCADA Displays
• Alarm Management
• Change Management
• Controller Qualifications
• Operating Experience
• Validation

65
Other Areas Mentioned

• Planning events to enhance communication between
  other modes of transportation regarding control
  room lessons learned
• Sponsoring workshops for pipeline operators to
  share best practices
• Encouraging the development of consensus-based
  best practices to promote controller success
• Initiating a research and development project to
  establish a web-based generic simulation tool to
  help train controllers of smaller pipeline
  operators

66
Safety Pyramid
Serious Failure
Reportable
Significant and Minor Events
Un-reportable
Intervention by Controllers, other Personnel
or Safety Systems
Recorded
Near Miss, Identified
Un-recorded
Near Miss, Undetected
Control Room Management processes can help assure
that developing situations dont climb the
pyramid to become Significant Events or Serious
Failures
67
Conceptual Pipeline CRM Risk Matrix--- Risk
derived from monitor and control ---Red
indicates higher risk, Yellow indicates lower
risk
Matrix coding principally represents the
combination of frequency and consequence of
pipeline upset conditions and failures, where CRM
may be a contributing factor
68
Current Industry Efforts and Resources

• Standards Currently Being Developed
• CRM Standard by API
• Alarm API Recommended Practice 1167
• AGA Alarm Recommended Practice/Standard
• Additional Efforts in Operator Qualifications

69
Existing Relevant Standards

• Standards Existing or Previously in Development
  During Draft NPRM Stages
• API RP1165 Recommended Practice for Pipeline
  SCADA Displays
• EEMUA 191 A Guide to Design, Alarm Management,
  Procurement
• (The Engineering Equipment and Materials
  Users Association)
• ISA- SP18 Instrument Signals and Alarms
• ASME/ANSI B31Q, Pipeline Personnel Qualification
• API RP1118 Training and Qualification of Liquid
  Pipeline Controllers
• API RP1113 Developing a Pipeline Supervisory
  Control Center
• API 1164 Pipeline SCADA Security

70
CRM Rule-Making Status

• NPRM to account for changes in 49 CFR 192, 193
  and 195
• NPRM has been drafted Internal Review
• Expected Release of NPRM Mid-Summer 2008
• Performance Risk based approach
• (similar to IMP)
• Operators to address all applicable CRM risk
• factors

71

• http//dms.dot.gov
• New Docket No. PHMSA-2007-27954
• Old Docket No. RSPA-2004-18584
• Simple search on 27954 or 18584
• EXISTING CONTROL ROOM MANAGEMENT/CCERT
  INFORMATION

72
(No Transcript)
73
QUESTIONS?Karen Butler816-329-3835
74
Questions Answers

• Please send in your questions by
• Q A chat
• or
• Raise your hand to ask an audio question

75
(No Transcript)