ASME B31.8S 2014

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ASME B31.8S Managing System Integrity of Gas Pipelines

Published By	Publication Date	Number of Pages
ASME	2014	80

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Description

This ASME Standard covers on-shore, gas pipeline systems constructed with ferrous materials, including pipe, valves, appurtenances attached to pipe, compressor units, metering stations, regulator stations, delivery stations, holders and fabricated assemblies. Its principles, processes and approaches apply to the entire system for all pipeline systems. ASME B31.8S is specifically designed to provide the operator with the information necessary to develop and implement an effective integrity management program utilizing proven industry practices and processes. Effective system management can decrease repair and replacement costs, prevent malfunctions, and minimize system downtime. Key changes to this version include updates to the potential impact area requirements section and non-mandatory appendix A. Intended for: Gas pipeline owners/operators; pipeline operation and maintenance management and engineering departments; federal, state, and local regulatory bodies; and all groups responsible for gas pipeline system integrity.

PDF Catalog

PDF Pages	PDF Title
5	CONTENTS
7	FOREWORD
8	ASME B31 COMMITTEE ROSTER
12	SUMMARY OF CHANGES
13	1 INTRODUCTION 1.1 Scope 1.2 Purpose and Objectives 1.3 Integrity Management Principles
14	2 INTEGRITY MANAGEMENT PROGRAM OVERVIEW 2.1 General
15	Figures Fig. 2.1-1 Integrity Management Program Elements
16	Fig. 2.1-2 Integrity Management Plan Process Flow Diagram
17	2.2 Integrity Threat Classification
18	2.3 The Integrity Management Process 2.3.1 Identify Potential Pipeline Impact by Threat. 2.3.2 Gathering, Reviewing, and Integrating Data. 2.3.3 Risk Assessment. 2.3.4 Integrity Assessment.
19	2.3.5 Responses to Integrity Assessment, Mitigation Repair and Prevention, and Setting Inspection Intervals. 2.3.6 Update, Integrate, and Review Data. 2.3.7 Reassess Risk. 2.4 Integrity Management Program 2.4.1 Integrity Management Plan. 2.4.2 Performance Plan. 2.4.3 Communications Plan.
20	2.4.4 Management of Change Plan. 2.4.5 Quality Control Plan. 3 CONSEQUENCES 3.1 General 3.2 Potential Impact Area 3.2.1 Typical Natural Gas. 3.2.2 Other Gases.
21	3.2.3 Performance-Based Programs — Other Considerations. 3.2.4 Ranking of Potential Impact Areas. 3.3 Consequence Factors to Consider 4 GATHERING, REVIEWING, AND INTEGRATING DATA 4.1 General Fig. 3.2.4-1 Potential Impact Area
22	4.2 Data Requirements 4.2.1 Prescriptive Integrity Management Programs. 4.2.2 Performance-Based Integrity Management Programs. 4.3 Data Sources Tables Table 4.2.1-1 Data Elements for Prescriptive Pipeline Integrity Program
23	4.4 Data Collection, Review, and Analysis 4.5 Data Integration Table 4.3-1 Typical Data Sources for Pipeline Integrity Program
24	5 RISK ASSESSMENT 5.1 Introduction 5.2 Definition 5.3 Risk Assessment Objectives 5.4 Developing a Risk Assessment Approach
25	5.5 Risk Assessment Approaches
26	5.6 Risk Analysis 5.6.1 Risk Analysis for Prescriptive Integrity Management Programs. 5.6.2 Risk Analysis for Performance-Based Integrity Management Programs. 5.7 Characteristics of an Effective Risk Assessment Approach
27	Table 5.6.1-1 Integrity Assessment Intervals: Time-Dependent Threats, Internal and External Corrosion, Prescriptive Integrity Management Plan
28	5.8 Risk Estimates Using Assessment Methods 5.9 Data Collection for Risk Assessment 5.10 Prioritization for Prescriptive-Based and Performance-Based Integrity Management Programs
29	5.11 Integrity Assessment and Mitigation 5.12 Validation
30	6 INTEGRITY ASSESSMENT 6.1 General 6.2 Pipeline In-Line Inspection 6.2.1 Metal Loss Tools for the Internal and External Corrosion Threat.
31	6.2.2 Crack Detection Tools for the Stress Corrosion Cracking Threat. 6.2.3 Metal Loss and Caliper Tools for Third-Party Damage and Mechanical Damage Threat. 6.2.4 All Other Threats. 6.2.5 Special Considerations for the Use of In-Line Inspection Tools
32	6.2.6 Examination and Evaluation. 6.3 Pressure Testing 6.3.1 Time-Dependent Threats. 6.3.2 Manufacturing and Related Defect Threats. 6.3.3 All Other Threats. 6.3.4 Examination and Evaluation. 6.4 Direct Assessment 6.4.1 External Corrosion Direct Assessment ECDA for the External Corrosion Threat.
33	6.4.2 Internal Corrosion Direct Assessment ICDA Process for the Internal Corrosion Threat. 6.4.3 Stress Corrosion Cracking Direct Assessment SCCDA for the Stress Corrosion Cracking Threat. 6.4.4 All Other Threats. 6.5 Other Integrity Assessment Methodologies
34	7 RESPONSES TO INTEGRITY ASSESSMENTS AND MITIGATION REPAIR AND PREVENTION 7.1 General 7.2 Responses to Pipeline In-Line Inspections 7.2.1 Metal Loss Tools for Internal and External Corrosion. 7.2.2 Crack Detection Tools for Stress Corrosion Cracking.
35	Table 7.1-1 Acceptable Threat Prevention and Repair Methods
37	7.2.3 Metal Loss and Caliper Tools for Third-Party Damage and Mechanical Damage. 7.2.4 Limitations to Response Times for Prescriptive-Based Program. Fig. 7.2.1-1 Timing for Scheduled Responses: Time-Dependent Threats, Prescriptive Integrity Management Plan
38	7.2.5 Extending Response Times for Performance-Based Program. 7.3 Responses to Pressure Testing 7.3.1 External and Internal Corrosion Threats. 7.3.2 Stress Corrosion Cracking Threat. 7.3.3 Manufacturing and Related Defect Threats. 7.4 Responses to Direct Assessment Inspections 7.4.1 External Corrosion Direct Assessment ECDA. 7.4.2 Internal Corrosion Direct Assessment ICDA. 7.4.3 Stress Corrosion Cracking Direct Assessment SCCDA. 7.5 Timing for Scheduled Responses
39	7.6 Repair Methods 7.7 Prevention Strategy/Methods 7.8 Prevention Options 8 INTEGRITY MANAGEMENT PLAN 8.1 General
40	8.2 Updating the Plan 8.3 Plan Framework 8.3.1 Gathering, Reviewing, and Integrating Data. 8.3.2 Assess Risk. 8.3.3 Integrity Assessment. 8.3.4 Responses to Integrity Assessment, Mitigation Repair and Prevention, and Intervals.
41	9 PERFORMANCE PLAN 9.1 Introduction 9.2 Performance Measures Characteristics Table 8.3.4-1 Example of Integrity Management Plan for Hypothetical Pipeline Segment (Segment Data: Line 1, Segment 3)
42	9.2.1 Process or Activity Measures. 9.2.2 Operational Measures. 9.2.3 Direct Integrity Measures. Table 8.3.4-2 Example of Integrity Management Plan for Hypothetical Pipeline Segment (Integrity Assessment Plan: Line 1, Segment 3)
43	9.3 Performance Measurement Methodology 9.4 Performance Measurement: Intrasystem Table 9.2.3-1 Performance Measures
44	Table 9.4-1 Performance Metrics
45	9.5 Performance Measurement: Industry Based 9.6 Performance Improvement Table 9.4-2 Overall Performance Measures
46	10 COMMUNICATIONS PLAN 10.1 General 10.2 External Communications 10.3 Internal Communications 11 MANAGEMENT OF CHANGE PLAN
47	12 QUALITY CONTROL PLAN 12.1 General 12.2 Quality Management Control
48	13 TERMS, DEFINITIONS, AND ACRONYMS
49	Fig. 13-1 Hierarchy of Terminology for Integrity Assessment
54	14 REFERENCES AND STANDARDS
57	NONMANDATORY APPENDIX A THREAT PROCESS CHARTS AND PRESCRIPTIVE INTEGRITY MANAGEMENT PLANS A-1 EXTERNAL CORROSION THREAT A-1.1 Scope A-1.2 Gathering, Reviewing, and Integrating Data A-1.3 Criteria and Risk Assessment A-1.4 Integrity Assessment
59	A-1.5 Responses and Mitigation A-1.6 Other Data A-1.7 Assessment Interval A-1.8 Performance Measures A-2 INTERNAL CORROSION THREAT A-2.1 Scope A-2.2 Gathering, Reviewing, and Integrating Data
61	A-2.3 Criteria and Risk Assessment A-2.4 Integrity Assessment A-2.5 Responses and Mitigation A-2.6 Other Data A-2.7 Assessment Interval
62	A-2.8 Performance Metrics A-3 STRESS CORROSION CRACKING THREAT A-3.1 Scope A-3.2 Gathering, Reviewing, and Integrating Data A-3.3 Criteria and Threat Assessment A.3.3.1 Possible Threat of Near-Neutral pH SCC. A-3.3.2 Possible Threat of High pH SCC. A-3.3.3 Additional Considerations. A-3.4 Integrity Assessment
63	A-3.4.1 Bell Hole Examination and Evaluation Method. A-3.4.2 Hydrostatic Testing for SCC. A-3.4.3 In-Line Inspection for SCC. A-3.4.4 Stress Corrosion Cracking Direct Assessment SCCDA. A-3.5 Other Data A-3.6 Performance Measures
65	A-4 MANUFACTURING THREAT PIPE SEAM AND PIPE A-4.1 Scope A-4.2 Gathering, Reviewing, and Integrating Data A-4.3 Criteria and Risk Assessment A-4.4 Integrity Assessment A-4.5 Responses and Mitigation A-4.6 Other Data A-4.7 Assessment Interval
67	A-4.8 Performance Measures A-5 CONSTRUCTION THREAT PIPE GIRTH WELD, FABRICATION WELD, WRINKLE BEND OR BUCKLE, STRIPPED THREADS/BROKEN PIPE/COUPLING A-5.1 Scope A-5.2 Gathering, Reviewing, and Integrating Data A-5.3 Criteria and Risk Assessment A-5.4 Integrity Assessment A-5.5 Responses and Mitigation A-5.6 Other Data A-5.7 Assessment Interval
69	A-5.8 Performance Measures A-6 EQUIPMENT THREAT GASKETS AND O-RINGS, CONTROL/RELIEF, SEAL/PUMP PACKING A-6.1 Scope A-6.2 Gathering, Reviewing, and Integrating Data A-6.3 Criteria and Risk Assessment A-6.4 Integrity Assessment A-6.5 Responses and Mitigation A-6.6 Other Data A-6.7 Assessment Interval A-6.8 Performance Measures A-7 THIRD-PARTY DAMAGE THREAT THIRD-PARTY INFLICTED DAMAGE IMMEDIATE, VANDALISM, PREVIOUSLY DAMAGED PIPE A-7.1 Scope
72	A-7.2 Gathering, Reviewing, and Integrating Data A-7.3 Criteria and Risk Assessment A-7.4 Integrity Assessment A-7.5 Responses and Mitigation A-7.6 Other Data A-7.7 Assessment Interval A-7.8 Performance Measures A-8 INCORRECT OPERATIONS THREAT A-8.1 Scope A-8.2 Gathering, Reviewing, and Integrating Data
74	A-8.3 Criteria and Risk Assessment A-8.4 Integrity Assessment A-8.5 Responses and Mitigation A-8.6 Other Data A-8.7 Assessment Interval A-8.8 Performance Measures A-9 WEATHER-RELATED AND OUTSIDE FORCE THREAT EARTH MOVEMENT, HEAVY RAINS OR FLOODS, COLD WEATHER, LIGHTNING A-9.1 Scope A-9.2 Gathering, Reviewing, and Integrating Data A-9.3 Criteria and Risk Assessment
76	A-9.4 Integrity Assessment A-9.5 Responses and Mitigation A-9.6 Other Data A-9.7 Assessment Interval A-9.8 Performance Measures
77	NONMANDATORY APPENDIX B DIRECT ASSESSMENT PROCESS B-1 EXTERNAL CORROSION DIRECT ASSESSMENT B-2 INTERNAL CORROSION DIRECT ASSESSMENT
78	NONMANDATORY APPENDIX C PREPARATION OF TECHNICAL INQUIRIES C-1 INTRODUCTION C-2 REQUIREMENTS C-3 SUBMITTAL