AS 2885.1-1997

1 - AS 2885.1-1997 PIPELINES-GAS AND LIQUID PETROLEUM - DESIGN AND CONSTRUCTION
4 - PREFACE
5 - CONTENTS
7 - SECTION 1 SCOPE AND GENERAL
7 - 1.0 BASIS OF AS 2885 SERIES OF STANDARDS
7 - 1.1 SCOPE
8 - 1.2 EXCLUSIONS
8 - 1.3 RETROSPECTIVE APPLICATION
8 - 1.4 DEPARTURES FROM THIS STANDARD
8 - 1.5 REFERENCED DOCUMENTS
8 - 1.6 INTERPRETATIONS
8 - 1.7 CONVERSION TO SI UNITS
9 - 1.8 ROUNDING OF NUMBERS
9 - 1.9 NOTATION
9 - 1.10 DEFINITIONS
9 - 1.10.1 Accessory
9 - 1.10.2 Actual yield stress (AYS)
9 - 1.10.3 Approved and approval
9 - 1.10.4 Buckle
9 - 1.10.5 Casing
9 - 1.10.6 Collapse
9 - 1.10.7 Component
9 - 1.10.8 Construction
9 - 1.10.9 Control piping
9 - 1.10.10 Defect
9 - 1.10.11 Dent
9 - 1.10.12 Diameter
9 - 1.10.13 Fitting
9 - 1.10.14 Fluid
10 - 1.10.15 Gas
10 - 1.10.16 Heat
10 - 1.10.17 High vapour pressure liquid (HVPL)
10 - 1.10.18 Hoop stress
10 - 1.10.19 Hot tap
10 - 1.10.20 Imperfection
10 - 1.10.21 Inert gas
10 - 1.10.22 Inspector
10 - 1.10.23 Leak test
10 - 1.10.24 Location class
10 - 1.10.25 Mainline pipework
10 - 1.10.26 Maximum allowable operating pressure (MAOP)
10 - 1.10.27 May
10 - 1.10.28 Mechanical interference-fit joint
10 - 1.10.29 Not applicable
10 - 1.10.30 Operating authority
10 - 1.10.31 Petroleum
10 - 1.10.32 Pig
10 - 1.10.33 Pig trap (scraper trap)
10 - 1.10.34 Piping
10 - 1.10.35 Pre-tested
10 - 1.10.36 Pressure strength
11 - 1.10.37 Proprietary item
11 - 1.10.38 Protection measures-Procedural
11 - 1.10.39 Protection measures-Physical
11 - 1.10.40 Regulatory authority
11 - 1.10.41 Riser
11 - 1.10.42 Shall
11 - 1.10.43 Should
11 - 1.10.44 Sour service
11 - 1.10.45 Specified minimum yield stress (SMYS)
11 - 1.10.46 Station pipework
11 - 1.10.47 Strength test
11 - 1.10.48 Telescoped pipeline
11 - 1.10.49 Wall thickness, nominal
11 - 1.10.50 Nominated Standard
12 - SECTION 2 SAFETY
12 - 2.1 BASIS OF SECTION
12 - 2.2 GENERAL
12 - 2.2.1 Risk assessment methodology
12 - 2.2.2 Approval
12 - 2.2.3 Implementation
12 - 2.3 RISK IDENTIFICATION
12 - 2.3.1 Location analysis
13 - 2.3.2 Threat analysis
13 - 2.3.3 External interference protection design
13 - 2.3.4 Failure analysis
13 - 2.3.5 Determination of hazardous events
13 - 2.4 RISK EVALUATION
13 - 2.4.1 General
13 - 2.4.2 Frequency analysis
14 - 2.4.3 Consequence analysis
14 - 2.4.4 Risk ranking
15 - 2.5 MANAGEMENT OF RISKS
15 - 2.5.1 General
15 - 2.5.2 Design stage
16 - 2.5.3 Operating pipelines
16 - 2.6 OCCUPATIONAL HEALTH AND SAFETY
16 - 2.7 ELECTRICAL SAFETY
16 - 2.8 CONSTRUCTION SAFETY
18 - SECTION 3 MATERIALS AND COMPONENTS
18 - 3.0 BASIS OF SECTION
18 - 3.1 QUALIFICATION OF MATERIALS AND COMPONENTS
18 - 3.1.1 General
18 - 3.1.2 Materials and components complying with nominated Standards
18 - 3.1.3 Materials and components complying with Standards not nominated in this Standard
19 - 3.1.4 Components, other than pipe, for which no Standards exist
19 - 3.1.5 Reclaimed pipe
19 - 3.1.6 Reclaimed accessories, valves and fittings
19 - 3.1.7 Material and components not fully identified
19 - 3.1.8 Identification of components
20 - 3.1.9 Unidentified materials and components
20 - 3.1.10 Hydrostatic test
20 - 3.2 PRESSURE-CONTAINING COMPONENTS
20 - 3.3 CARBON EQUIVALENT
20 - 3.4 YIELD STRESS
20 - 3.5 FRACTURE TOUGHNESS
20 - 3.6 HEATED OR HOT-WORKED ITEMS
21 - 3.7 RECORDS
22 - SECTION 4 PIPELINE DESIGN
22 - 4.1 BASIS OF SECTION
23 - 4.2 PIPELINE GENERAL
23 - 4.2.1 Design criteria
25 - 4.2.2 Design life
25 - 4.2.3 Maximum allowable operating pressure (MAOP)
25 - 4.2.4 Route
27 - 4.2.5 External interference protection
32 - 4.2.6 Control and management of the pipeline system
35 - 4.3 PIPELINE DESIGN
35 - 4.3.1 General
36 - 4.3.2 Design pressure
36 - 4.3.3 Design temperatures
36 - 4.3.4 Wall thickness
37 - 4.3.5 Control, instrument and sampling piping
38 - 4.3.6 Stress and strain
41 - 4.3.7 Fracture control
47 - 4.3.8 Special construction
48 - 4.3.9 Pipeline assemblies
50 - 4.3.10 Jointing
50 - 4.3.11 Supports and anchors
51 - 4.4 STATIONS
51 - 4.4.1 General
51 - 4.4.2 Design
54 - 4.4.3 Safety
55 - 4.4.4 Station pipework
55 - 4.4.5 Station equipment
56 - 4.4.6 Structures
57 - 4.4.7 Corrosion protection
57 - 4.4.8 Electrical installations
57 - 4.4.9 Drainage
59 - SECTION 5 MITIGATION OF CORROSION
59 - 5.1 BASIS OF SECTION
59 - 5.2 PERSONNEL
59 - 5.3 RATE OF DEGRADATION
59 - 5.3.1 Assessment
59 - 5.3.2 Internal corrosion
59 - 5.3.3 External corrosion
59 - 5.3.4 Environment-related cracking
60 - 5.4 CORROSION MITIGATION
60 - 5.4.1 General
60 - 5.4.2 Corrosion mitigation methods
60 - 5.4.3 Corrosion allowance
60 - 5.5 CORROSION MONITORING
61 - 5.6 INTERNAL CORROSION MITIGRATION METHODS
61 - 5.6.1 General
61 - 5.6.2 Internal lining
61 - 5.6.3 Corrosion inhibitors and biocides
61 - 5.7 EXTERNAL CORROSION MITIGATION METHODS
61 - 5.7.1 General
61 - 5.7.2 Coating
62 - 5.7.3 Cathodic protection
62 - 5.7.4 Protection criteria
62 - 5.7.5 Design considerations
63 - 5.7.6 Measurement of potential
64 - 5.7.7 Electrical earthing
64 - 5.8 EXTERNAL ANTI-CORROSION COATING
64 - 5.8.1 Coating system
64 - 5.8.2 Coating selection
64 - 5.8.3 Coating application
64 - 5.8.4 Joint and coating repair
65 - 5.9 INTERNAL LINING
65 - 5.9.1 Pipeline lining
65 - 5.9.2 Joint and repair lining
66 - SECTION 6 CONSTRUCTION
66 - 6.1 BASIS OF SECTION
66 - 6.2 SURVEY
66 - 6.3 HANDLING OF COMPONENTS
66 - 6.3.1 General
66 - 6.3.2 Pipe transport
66 - 6.3.3 Construction loads
66 - 6.4 INSPECTION OF PIPE AND COMPONENTS
66 - 6.4.1 General
67 - 6.4.2 Ovality
67 - 6.4.3 Buckles
67 - 6.4.4 Dents
67 - 6.4.5 Gouges, grooves and notches
67 - 6.4.6 Repair of defects
67 - 6.4.7 Laminations and notches
67 - 6.5 CHANGES IN DIRECTION
67 - 6.5.1 Accepted methods for changes in direction
67 - 6.5.2 Internal access
68 - 6.5.3 Changing direction at a butt-weld
68 - 6.5.4 Use of heat
68 - 6.5.5 Bend fabricated from a forged bend or an elbow
68 - 6.5.6 Roped bends
68 - 6.6 COLD-FIELD BENDS
68 - 6.6.1 General
68 - 6.6.2 Qualification of cold-field bending procedure
68 - 6.6.3 Acceptance limits for field bends
69 - 6.7 FLANGED JOINTS
69 - 6.8 COVERING SLABS, BOX CULVERTS, CASINGS AND TUNNELS
70 - 6.9 SYSTEM CONTROLS
70 - 6.10 ATTACHMENT OF ELECTRICAL CONDUCTORS
70 - 6.10.1 General
70 - 6.10.2 Aluminothermic welding with qualification
71 - 6.11 LOCATION
71 - 6.11.1 Position
71 - 6.11.2 Clearances
71 - 6.12 CLEARING AND GRADING
71 - 6.13 TRENCH CONSTRUCTION
71 - 6.13.1 Safety
71 - 6.13.2 Separation of topsoil
71 - 6.13.3 Dimensions of trenches
71 - 6.13.4 Bottoms of trenches
71 - 6.13.5 Scour
72 - 6.14 INSTALLATION OF A PIPE IN A TRENCH
72 - 6.15 PLOUGHING-IN AND DIRECTIONALLY DRILLED PIPELINES
72 - 6.16 REINSTATEMENT
72 - 6.17 CLEANING AND GAUGING PIPELINES
72 - 6.18 RECORDS
74 - SECTION 7 INSPECTIONS AND TESTING
74 - 7.1 GENERAL
74 - 7.2 INSPECTION AND TEST PLAN AND PROCEDURES
74 - 7.3 PERSONNEL
74 - 7.4 PRESSURE TESTING
74 - 7.4.1 Application
74 - 7.4.2 Exemptions from a field pressure test
74 - 7.4.3 Test procedure
74 - 7.4.4 Minimum test pressures
75 - 7.4.5 Testing with a gas
76 - 7.4.6 Pressure testing loads
76 - 7.4.7 Acceptance criteria
76 - 7.5 COMMENCEMENT OF PATROLLING
76 - 7.6 RECORDS
77 - APPENDIX A - REFERENCED DOCUMENTS
77 - A1 IDENTIFICATION OF DOCUMENTS
77 - A2 REFERENCED DOCUMENTS
81 - APPENDIX B - ELECTRICAL HAZARDS ON PIPELINES AND INTERACTION WITH CATHODIC PROTECTION (CP)
81 - B1 INTRODUCTION
81 - B2 CATEGORIES
81 - B3 HAZARD MECHANISMS
81 - B4 LOW FREQUENCY INDUCTION (LFI)
83 - B5 A.C. ELECTRIFIED RAILWAY OR SINGLE WIRE EARTH RETURN (SWER) LINES
83 - B6 EARTH POTENTIAL RISE (ERP)
85 - B7 CAPACITIVE COUPLING
85 - B8 INTERACTION OF ELECTRICAL PROTECTION WITH CP
85 - B9 FARADAY CAGES
85 - B10 OTHER HAZARDS
86 - B11 CONCLUSION
87 - APPENDIX C - PREFERRED METHOD FOR TENSILE TESTING OF WELDED LINE PIPE DURING MANUFACTURE
87 - C1 APPLICABILITY
87 - C2 METHOD FOR DETERMINING TENSILE PROPERTIES
87 - C3 CRITERIA OF ACCEPTANCE
88 - APPENDIX D - FRACTURE TOUGHNESS TEST METHODS
88 - D1 SCOPE
88 - D2 SAMPLING
88 - D3 FRACTURE APPEARANCE TESTING FOR CONTROL OF BRITTLE FRACTURE
88 - D3.1 General
88 - D3.2 Test specimens
88 - D3.3 Test temperature
88 - D3.4 Criteria of acceptance
88 - D4 ENERGY ABSORPTION TESTING FOR CONTROL OF LOW ENERGY TEARING DUCTILE FRACTURE
88 - D4.1 General
88 - D4.2 Test specimens
89 - D4.3 Test temperature
89 - D4.4 Criteria of acceptance
90 - APPENDIX E - DESIGN CONSIDERATIONS FOR EXTERNAL INTERFERENCE PROTECTION
90 - E1 INTRODUCTION
90 - E2 DEFINITION OF DESIGN EVENTS
91 - E3 PROTECTION DESIGN
92 - E4 PENETRATION RESISTANCE
93 - APPENDIX F - FRACTURE CONTROL PLAN FOR STEEL PIPELINES
93 - F1 SCOPE
93 - F2 FACTORS AFFECTING BRITTLE AND TEARING (DUCTILE) FRACTURE
93 - F2.1 General
93 - F2.2 Exclusions
93 - F2.3 Fluid parameters
94 - F2.4 Operating parameters
95 - F2.5 Calculation of Charpy energy requirements for the arrest of ductile tearing fracture
97 - APPENDIX G - FACTORS AFFECTING CORROSION
97 - GI GENERAL
97 - G2 INTERNAL CORROSION
97 - G3 EXTERNAL CORROSION
98 - G4 ENVIRONMENT RELATED CRACKING
99 - APPENDIX H - ENVIRONMENT RELATED CRACKING
99 - H1 GENERAL
99 - H2 HIGH pH (CLASSICAL) STRESS CORROSION CRACKING
99 - H2.1 Description
99 - H2.2 Conditions
100 - H3 LOW pH (NEAR NEUTRAL) STRESS CORROSION CRACKING
100 - H3.1 Description
100 - H3.2 Conditions
100 - H4 HYDROGEN SULFIDE CRACKING
100 - H4.1 General
100 - H4.2 HIC
101 - H4.3 SSC
101 - H4.4 Mitigation
101 - H5 DESIGN CONSIDERATIONS TO MITIGATE STRESS- CORROSION CRACKING
101 - H5.1 General
101 - H5.2 Stress
102 - H5.3 Cyclic variation of stress
102 - H5.4 Pipeline anti-corrosion coating
102 - H5.5 Surface condition
102 - H5.6 Cathodic protection system
102 - H5.7 Pipe wall temperature
103 - APPENDIX I - INFORMATION FOR CATHODIC PROTECTION
104 - APPENDIX J - PROCEDURE QUALIFICATION FOR COLD FIELD BENDS
104 - J1 INTRODUCTION
104 - J2 BASIS OF REQUIREMENTS FOR COLD FIELD BENDS
105 - J3 OBJECTIVES
105 - J4 SUGGESTED METHOD
108 - INDEX

Specifies requirements for the design and construction of steel pipelines and associated piping components that are used to transmit single phase and multiphase hydrocarbon fluids. Applies where the temperature of a fluid is within the range of -30 degrees Celsius to 200 degrees Celsius, and either the maximum allowable operating pressure is more than 1050 kPa or the hoop stress exceeds 20 percent of the specified minimum yield.

This Standard specifies requirements for the design and construction of steel pipelines and associated piping and components that are used to transmit single phase and multiphase hydrocarbon fluids, such as natural and manufactured gas, liquefied petroleum gas, natural gasoline, crude oil, natural gas liquids and liquid petroleum products. The Standard applies where-(a) the temperatures of the fluid are not more than 200C nor less than -30C; and (b) either the maximum allowable operating pressure (MAOP) of the pipeline is more than 1050 kPa, or at one or more positions in the pipeline the hoop stress exceeds 20% of the SMYS.Except for the exclusions listed in Clause 1.2, this Standard applies to flowlines and gathering pipelines on land and between submarine production facilities. The Standard also applies to pipelines between terminals (see Figures 1.1(A) and 1.1(B)). The extent of the pipelines extends only to where the pipeline is connected to facilities designed according to other Standards. In general, flowlines commence at the wellhead assembly outlet valve on a wellhead, terminate at the inlet valve of the collection manifold, and include piping within facilities integral with the pipeline, such as compressor stations, pump stations, valve stations and metering stations.

First published in part as part of AS CB28-1972.
Revised and redesignated AS 1697-1975.
AS 1958 first published 1976.
AS 2018 first published 1977.
Second edition AS 1697-1979.
Third edition 1981.
Second edition AS 1958-1981.
Second edition AS 2018-1981.
AS 1958-1981 and parts of AS 1697-1981 and AS 2018-1981 revised, amalgmated and redesignated AS 2885-1987.
Parts of AS 1697-1981, AS 2018-1981 and AS 2885-1987 revised, amalgamated and redesignated in part as AS 2885.1-1997.