Petroleum and natural gas industry - Pipeline transportation systems - Pipeline integrity management specification - Part 2: Full-life cycle integritymanagement for offshore pipeline (ISO 19345-2:2019)

This document specifies requirements and gives recommendations on integrity management of pipeline during the design, construction, commission, operation, maintenance and abandonment. It applies to offshore pipeline for transporting petroleum and natural gas.
This document applies to rigid pipelines. It is not applicable for flexible pipelines, dynamic risers or those constructed from other materials, such as glass-reinforced plastics. An offshore pipeline system extends to
 The first valve, flange or connection above water on platform or subsea mechanical connector with dynamic riser.
 The connection point to the offshore installation (i.e. piping manifolds are not included).
 The first valve, flange, connection or isolation joint at a landfall unless otherwise specified by the onshore legislation.
The components mentioned above (valve, flange, connection, isolation joint) include also any pup pieces, i.e. the offshore pipeline system extends to the weld beyond the pup piece.
Offshore pipelines are defined as pipelines that use universally recognized offshore pipeline construction techniques.

Erdöl- und Erdgasindustrie - Leitfaden für das Integritätsmanagement von Fernleitungen - Teil 2: Integritätsmanagement des vollständigen Lebenszyklus von Offshore Fernleitungen (ISO 19345-2:2019)

PNGI - Spécifications de gestion de l’intégrité des pipelines - Partie 2: Gestion de l’intégrité des pipelines marins durant leur cycle de vie complet (ISO 19345-2:2019)

Le présent document spécifie des exigences et fournit des recommandations relatives à la gestion de l'intégrité d'un système de conduite durant son cycle de vie, ce qui inclut la conception, la construction, la mise en service, l'exploitation, la maintenance et l'abandon.
Le présent document est applicable aux conduites en mer utilisées pour le transport du pétrole et du gaz naturel. Il est applicable aux conduites rigides en acier. Il n'est pas applicable aux conduites flexibles, aux colonnes montantes dynamiques ou aux conduites fabriquées dans d'autres matériaux tels que le plastique renforcé de verre.
NOTE 1    Un système de conduite en mer s'étend:
—           à la première vanne, à la première bride ou au premier raccordement au-dessus de l'eau sur la plate-forme ou raccord mécanique sous-marin avec la structure sous-marine (c'est-à-dire le collecteur ou la colonne montante dynamique);
—           au point de raccordement à l'installation en mer (c'est-à-dire que les tuyauteries des collecteurs des canalisations ne sont pas inclus);
—           à la première vanne, à la première bride, au premier raccordement ou joint isolant d'un atterrage, sauf spécification contraire de la législation terrestre.
NOTE 2    Les composants indiqués ci-dessus (vanne, bride, raccord, joint isolant) comprennent également tout élément de manchon, c'est-à-dire que le système de conduite en mer s'étend jusqu'à la soudure située au-delà du manchon (voir Figure 1).
Le présent document est utilisé pour la gestion de l'intégrité, laquelle débute à l'étape de conception et de construction de la conduite. Lorsque les exigences de la norme de conception et de construction (par exemple ISO 13623) sont différentes, les dispositions du présent document amélioreront la conception et la construction du point de vue de l'intégrité.

Industrija za predelavo nafte in zemeljskega plina - Transportni cevovodni sistemi - Specifikacija za upravljanje celovitosti cevovoda - 2. del: Upravljanje celovitosti podvodnega cevovoda v celotnem življenjskem ciklu (ISO 19345-2:2019)

Ta dokument določa zahteve in podaja priporočila za upravljanje celovitosti cevovoda med načrtovanjem, gradnjo, vzpostavljanjem za zagon, obratovanjem, vzdrževanjem in opustitvijo. Uporablja se za podvodni cevovod, namenjen transportu nafte in zemeljskega plina.
Ta dokument se uporablja za toge cevovode. Ne uporablja se za gibljive cevovode, dinamične dvižne cevi ali tiste, ki so izdelane iz drugih materialov, kot je armirani poliester. Podvodni cevovod zajema:
– prvi ventil, prirobnico ali spojko nad vodo na ploščadi ali podvodno mehansko spojko z dinamično dvižno cevjo;
– priključek cevovoda na plavajočih objektih (npr. cevni razdelilniki niso vključeni);
– prvi ventil, prirobnica, spojka ali izolirni spoj na obali, razen če je na kopnem določeno drugače z zakonodajo.
Zgoraj omenjene komponente (ventil, prirobnica, spojka, izolirni spoj) vključujejo tudi priključke, tj. podvodni cevovodni sistem zajema varjeni del za priključkom.
Podvodni cevovod je opredeljen kot cevovod, ki uporablja splošno priznane tehnike gradnje podvodnih cevovodov.

General Information

Status
Published
Public Enquiry End Date
28-Feb-2018
Publication Date
04-Jul-2019
Technical Committee
Current Stage
6060 - National Implementation/Publication (Adopted Project)
Start Date
20-Jun-2019
Due Date
25-Aug-2019
Completion Date
05-Jul-2019

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SLOVENSKI STANDARD
SIST EN ISO 19345-2:2019
01-september-2019
Industrija za predelavo nafte in zemeljskega plina - Transportni cevovodni sistemi
- Specifikacija za upravljanje celovitosti cevovoda - 2. del: Upravljanje celovitosti
podvodnega cevovoda v celotnem življenjskem ciklu (ISO 19345-2:2019)
Petroleum and natural gas industry - Pipeline transportation systems - Pipeline integrity
management specification - Part 2: Full-life cycle integritymanagement for offshore
pipeline (ISO 19345-2:2019)
Erdöl- und Erdgasindustrie - Leitfaden für das Integritätsmanagement von Fernleitungen
- Teil 2: Integritätsmanagement des vollständigen Lebenszyklus von Offshore
Fernleitungen (ISO 19345-2:2019)
PNGI - Spécifications de gestion de l’intégrité des pipelines - Partie 2: Gestion de
l’intégrité des pipelines marins durant leur cycle de vie complet (ISO 19345-2:2019)
Ta slovenski standard je istoveten z: EN ISO 19345-2:2019
ICS:
75.200 Oprema za skladiščenje Petroleum products and
nafte, naftnih proizvodov in natural gas handling
zemeljskega plina equipment
SIST EN ISO 19345-2:2019 en,fr,de
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

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SIST EN ISO 19345-2:2019

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SIST EN ISO 19345-2:2019


EN ISO 19345-2
EUROPEAN STANDARD

NORME EUROPÉENNE

June 2019
EUROPÄISCHE NORM
ICS 75.200
English Version

Petroleum and natural gas industry - Pipeline
transportation systems -Pipeline integrity management
specification - Part 2: Full-life cycle integrity management
for offshore pipeline (ISO 19345-2:2019)
Industries du pétrole et du gaz naturel - Systèmes de Erdöl- und Erdgasindustrie -
transport par conduites - Spécification de gestion de Fernleitungstransportsysteme - Leitfaden für das
l'intégrité des conduites - Partie 2: Gestion de Integritätsmanagement von Fernleitungen - Teil 2:
l'intégrité des conduites en mer pendant leur cycle de Integritätsmanagement des vollständigen
vie complet (ISO 19345-2:2019) Lebenszyklus von Offshore Fernleitungen (ISO 19345-
2:2019)
This European Standard was approved by CEN on 9 February 2019.

CEN members are bound to comply with the CEN/CENELEC Internal Regulations which stipulate the conditions for giving this
European Standard the status of a national standard without any alteration. Up-to-date lists and bibliographical references
concerning such national standards may be obtained on application to the CEN-CENELEC Management Centre or to any CEN
member.

This European Standard exists in three official versions (English, French, German). A version in any other language made by
translation under the responsibility of a CEN member into its own language and notified to the CEN-CENELEC Management
Centre has the same status as the official versions.

CEN members are the national standards bodies of Austria, Belgium, Bulgaria, Croatia, Cyprus, Czech Republic, Denmark, Estonia,
Finland, Former Yugoslav Republic of Macedonia, France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia, Lithuania,
Luxembourg, Malta, Netherlands, Norway, Poland, Portugal, Romania, Serbia, Slovakia, Slovenia, Spain, Sweden, Switzerland,
Turkey and United Kingdom.





EUROPEAN COMMITTEE FOR STANDARDIZATION
COMITÉ EUROPÉEN DE NORMALISATION

EUROPÄISCHES KOMITEE FÜR NORMUNG

CEN-CENELEC Management Centre: Rue de la Science 23, B-1040 Brussels
© 2019 CEN All rights of exploitation in any form and by any means reserved Ref. No. EN ISO 19345-2:2019 E
worldwide for CEN national Members.

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SIST EN ISO 19345-2:2019
EN ISO 19345-2:2019 (E)
Contents Page
European foreword . 3

2

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SIST EN ISO 19345-2:2019
EN ISO 19345-2:2019 (E)
European foreword
This document (EN ISO 19345-2:2019) has been prepared by Technical Committee ISO/TC 67
"Materials, equipment and offshore structures for petroleum, petrochemical and natural gas industries"
in collaboration with Technical Committee CEN/TC 12 “Materials, equipment and offshore structures
for petroleum, petrochemical and natural gas industries” the secretariat of which is held by NEN.
This European Standard shall be given the status of a national standard, either by publication of an
identical text or by endorsement, at the latest by December 2019, and conflicting national standards
shall be withdrawn at the latest by December 2019.
Attention is drawn to the possibility that some of the elements of this document may be the subject of
patent rights. CEN shall not be held responsible for identifying any or all such patent rights.
According to the CEN-CENELEC Internal Regulations, the national standards organizations of the
following countries are bound to implement this European Standard: Austria, Belgium, Bulgaria,
Croatia, Cyprus, Czech Republic, Denmark, Estonia, Finland, Former Yugoslav Republic of Macedonia,
France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta,
Netherlands, Norway, Poland, Portugal, Romania, Serbia, Slovakia, Slovenia, Spain, Sweden, Switzerland,
Turkey and the United Kingdom.
Endorsement notice
The text of ISO 19345-2:2019 has been approved by CEN as EN ISO 19345-2:2019 without any
modification.

3

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SIST EN ISO 19345-2:2019

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SIST EN ISO 19345-2:2019
INTERNATIONAL ISO
STANDARD 19345-2
First edition
2019-05
Petroleum and natural gas industry —
Pipeline transportation systems
— Pipeline integrity management
specification —
Part 2:
Full-life cycle integrity management
for offshore pipeline
Industries du pétrole et du gaz naturel — Systèmes de transport par
conduites — Spécification de gestion de l'intégrité des conduites —
Partie 2: Gestion de l'intégrité des conduites en mer pendant leur
cycle de vie complet
Reference number
ISO 19345-2:2019(E)
©
ISO 2019

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SIST EN ISO 19345-2:2019
ISO 19345-2:2019(E)

COPYRIGHT PROTECTED DOCUMENT
© ISO 2019
All rights reserved. Unless otherwise specified, or required in the context of its implementation, no part of this publication may
be reproduced or utilized otherwise in any form or by any means, electronic or mechanical, including photocopying, or posting
on the internet or an intranet, without prior written permission. Permission can be requested from either ISO at the address
below or ISO’s member body in the country of the requester.
ISO copyright office
CP 401 • Ch. de Blandonnet 8
CH-1214 Vernier, Geneva
Phone: +41 22 749 01 11
Fax: +41 22 749 09 47
Email: copyright@iso.org
Website: www.iso.org
Published in Switzerland
ii © ISO 2019 – All rights reserved

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SIST EN ISO 19345-2:2019
ISO 19345-2:2019(E)

Contents Page
Foreword .vii
Introduction .viii
1 Scope . 1
2 Normative references . 3
3  Terms, definitions and abbreviated terms . 3
3.1 Terms and definitions . 3
3.2 Abbreviated terms . 7
4 General . 8
4.1 Key principles . 8
4.2 Integrity management program . 8
4.2.1 General. 8
4.2.2 Introduction to IMP elements. 8
4.3 Integrity management process elements .11
4.3.1 Data acquisition, review and integration .11
4.3.2 Risk assessment . .11
4.3.3 Inspection and monitoring .11
4.3.4 Integrity assessment .11
4.3.5 Mitigation activity .12
4.3.6 Performance measurement and improvement .12
4.3.7 Emergency response plan .12
4.3.8 Failure management plan .12
4.3.9 Remaining life assessment .12
4.4 Management elements .13
4.4.1 Policy and commitment .13
4.4.2 Scope of integrity management program .13
4.4.3 Organization structure, roles and responsibilities .13
4.4.4 Records and document control plan .13
4.4.5 Communication plan .13
4.4.6 Management of change plan .13
4.4.7 Management review and audit plan .14
4.4.8 Training and skill plan .14
5 Integrity management for the pipeline lifecycle phases.14
5.1 General .14
5.1.1 Objectives .14
5.1.2 Principles .14
5.2 Key lifecycle integrity processes .15
5.3 Lifecycle phases for integrity management .15
5.3.1 General.15
5.3.2 Feasibility .15
5.3.3 Design .16
5.3.4 Procurement .16
5.3.5 Fabrication .17
5.3.6 Transportation and storage .17
5.3.7 Integrity during installation .17
5.3.8 Pre-commissioning and commissioning .18
5.3.9 Handover — Preparation for operation.18
5.3.10 Operation and maintenance .19
5.3.11 Modifications during operations .20
5.3.12 Abandonment .20
6 Risk assessment .20
6.1 Definition of objectives and requirements .20
6.1.1 General.20
© ISO 2019 – All rights reserved iii

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SIST EN ISO 19345-2:2019
ISO 19345-2:2019(E)

6.1.2 Objectives .21
6.1.3 Requirements .21
6.2 Team definition .22
6.3 Segmentation .22
6.4 Threat identification .23
6.5 Probability of failure assessment .24
6.6 Consequence of failure assessment .24
6.6.1 Consequence assessment .24
6.6.2 Critical consequence areas analysis .25
6.7 Risk determination .25
6.8 Reporting .25
6.9 Reassessment .26
7 Inspection and monitoring .26
7.1 Inspection .27
7.1.1 General.27
7.1.2 Preparation for inspection .28
7.1.3 Requirements of equipment .28
7.1.4 Reporting requirements .29
7.1.5 Review of inspection results .31
7.2 Monitoring .31
7.2.1 Main monitoring activities .31
7.2.2 Identification and follow-up of available technology .31
7.2.3 Current and vibration monitoring .32
7.2.4 Monitoring of ship traffic and fishing activities .32
7.2.5 Leak detection .32
7.2.6 Review of monitoring data .33
8 Integrity assessment .33
8.1 General .33
8.2 Fitness for purpose .33
8.2.1 Assessment data collection .33
8.2.2 Defect data statistics and causation analysis .33
8.2.3 Assessment method selection .34
8.2.4 Residual strength and remaining life assessment . .34
8.3 Pressure test .36
8.3.1 General.36
8.3.2 Preconditions for use of pressure-testing on an in-service pipeline .36
8.3.3 Features to be considered for pressure test .37
8.3.4 Pressure test risks .37
8.3.5 Management measures .37
8.3.6 Monitoring of pressure test procedures .38
8.3.7 Review of pressure test results .38
8.3.8 Pressure test report.38
8.4 Direct assessment .38
8.4.1 General.38
8.4.2 Direct assessment process .39
8.4.3 Direct assessment methods .39
8.4.4 Limitations of direct assessment .39
8.5 Other assessment.39
9 Mitigation .39
9.1 General .39
9.2 Internal mitigation methods .42
9.3 External mitigation methods .42
9.4 Corrosion control systems .43
9.4.1 External corrosion .43
9.4.2 Internal corrosion and erosion .43
9.5 Management of unintended releases .44
9.6 MAOP reduction .44
iv © ISO 2019 – All rights reserved

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SIST EN ISO 19345-2:2019
ISO 19345-2:2019(E)

9.7 Emergency response .45
9.8 Repair methods .45
9.8.1 Repair methods selection .45
9.8.2 Detailed procedures .46
10 Performance measurement and improvement .47
10.1 General .47
10.2 Performance measurement.47
10.3 Management review .47
10.4 System audit .47
11 Data management .48
11.1 Data acquisition .48
11.1.1 Data acquisition content .48
11.1.2 Data acquisition method .48
11.1.3 Data alignment .48
11.2 Data transfer .49
11.3 Data integration .
...

SLOVENSKI STANDARD
oSIST prEN ISO 19345-2:2018
01-februar-2018
Industrija za predelavo nafte in zemeljskega plina - Transportni cevovodni sistemi
- Specifikacije za upravljanje celovitosti cevovoda - 2. del: Upravljanje celovitosti
podvodnega cevovoda v celotnem življenjskem ciklu (ISO/DIS 19345-2:2017)
Petroleum and natural gas industry - Pipeline transportation systems - Pipeline integrity
management specification - Part 2: Full-life cycle integritymanagement for offshore
pipeline (ISO/DIS 19345-2:2017)
Erdöl- und Erdgasindustrie - Leitfaden für das Integritätsmanagement von Fernleitungen
- Teil 2: Integritätsmanagement des vollständigen Lebenszyklus von Offshore
Fernleitungen (ISO/DIS 19345-2:2017)
PNGI - Spécifications de gestion de l’intégrité des pipelines - Partie 2: Gestion de
l’intégrité des pipelines marins durant leur cycle de vie complet (ISO/DIS 19345-2:2017)
Ta slovenski standard je istoveten z: prEN ISO 19345-2
ICS:
75.200 2SUHPD]DVNODGLãþHQMH Petroleum products and
QDIWHQDIWQLKSURL]YRGRYLQ natural gas handling
]HPHOMVNHJDSOLQD equipment
oSIST prEN ISO 19345-2:2018 en,fr,de
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

---------------------- Page: 1 ----------------------
oSIST prEN ISO 19345-2:2018

---------------------- Page: 2 ----------------------
oSIST prEN ISO 19345-2:2018
DRAFT INTERNATIONAL STANDARD
ISO/DIS 19345-2
ISO/TC 67/SC 2 Secretariat: UNI
Voting begins on: Voting terminates on:
2017-12-08 2018-03-02
Petroleum and natural gas industry — Pipeline
transportation systems — Pipeline integrity management
specification —
Part 2:
Full-life cycle integritymanagement for offshore pipeline
PNGI — Spécifications de gestion de l’intégrité des pipelines —
Partie 2: Gestion de l’intégrité des pipelines marins durant leur cycle de vie complet
ICS: 75.200
THIS DOCUMENT IS A DRAFT CIRCULATED
This document is circulated as received from the committee secretariat.
FOR COMMENT AND APPROVAL. IT IS
THEREFORE SUBJECT TO CHANGE AND MAY
NOT BE REFERRED TO AS AN INTERNATIONAL
STANDARD UNTIL PUBLISHED AS SUCH.
IN ADDITION TO THEIR EVALUATION AS
ISO/CEN PARALLEL PROCESSING
BEING ACCEPTABLE FOR INDUSTRIAL,
TECHNOLOGICAL, COMMERCIAL AND
USER PURPOSES, DRAFT INTERNATIONAL
STANDARDS MAY ON OCCASION HAVE TO
BE CONSIDERED IN THE LIGHT OF THEIR
POTENTIAL TO BECOME STANDARDS TO
WHICH REFERENCE MAY BE MADE IN
Reference number
NATIONAL REGULATIONS.
ISO/DIS 19345-2:2017(E)
RECIPIENTS OF THIS DRAFT ARE INVITED
TO SUBMIT, WITH THEIR COMMENTS,
NOTIFICATION OF ANY RELEVANT PATENT
RIGHTS OF WHICH THEY ARE AWARE AND TO
©
PROVIDE SUPPORTING DOCUMENTATION. ISO 2017

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oSIST prEN ISO 19345-2:2018
ISO/DIS 19345-2:2017(E)

COPYRIGHT PROTECTED DOCUMENT
© ISO 2017, Published in Switzerland
All rights reserved. Unless otherwise specified, no part of this publication may be reproduced or utilized otherwise in any form
or by any means, electronic or mechanical, including photocopying, or posting on the internet or an intranet, without prior
written permission. Permission can be requested from either ISO at the address below or ISO’s member body in the country of
the requester.
ISO copyright office
Ch. de Blandonnet 8 • CP 401
CH-1214 Vernier, Geneva, Switzerland
Tel. +41 22 749 01 11
Fax +41 22 749 09 47
copyright@iso.org
www.iso.org
ii © ISO 2017 – All rights reserved

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oSIST prEN ISO 19345-2:2018
ISO/DIS 19345-2:2017(E)
Contents
1. Scope.4
2. Normative references.6
3. Terms, definitions and abbreviated terms.6
4.General.11
5. Integrity management for the pipeline lifecycle phases.18
6. Risk assessment.25
7. Inspection and monitoring.32
8. Integrity assessment.39
9. Mitigation.46
10. Performance measurement and improvement.54
11. Data management.55
12. Pipeline integrity management within emergency response planning and failure management.57
13. Remaining life assessment and abandonment processes.60
14. Records and documents management.71
15. Communication.73
16. Management of change.74
17. Training and competency.74
© ISO 2017 – All rights reserved
i

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oSIST prEN ISO 19345-2:2018
ISO/DIS 19345-2:2017(E)
Foreword
ISO (the International Organization for Standardization) is a worldwide federation of national
standards bodies (ISO member bodies). The work of preparing International Standards is normally
carried out through ISO technical committees. Each member body interested in a subject for which a
technical committee has been established has the right to be represented on that committee.
International organizations, governmental and non-governmental, in liaison with ISO, also take part in
the work. ISO collaborates closely with the International Electrotechnical Commission (IEC) on all
matters of electrotechnical standardization.
The procedures used to develop this document and those intended for its further maintenance are
described in the ISO/IEC Directives, Part 2. In particular the different approval criteria needed for the
different types of ISO documents should be noted. This document was drafted in accordance with the
editorial rules of the ISO/IEC Directives, Part 1 (see www.iso.org/directives).
Attention is drawn to the possibility that some of the elements of this document may be the subject of
patent rights. ISO shall not be held responsible for identifying any or all such patent rights. Details of
any patent rights identified during the development of the document will be in the Introduction and/or
on the ISO list of patent declarations received (see www.iso.org/patents).
Any trade name used in this document is information given for the convenience of users and does not
constitute an endorsement.
For an explanation on the meaning of ISO specific terms and expressions related to conformity
assessment, as well as information about ISO's adherence to the World Trade Organization (WTO)
principles in the Technical Barriers to Trade (TBT) see the following URL:
www.iso.org/iso/foreword.html.
This document was prepared by Technical Committee ISO/TC 67, Materials, equipment and offshore
structures for the petroleum, petrochemical and natural gas industries, Subcommittee SC 2, Pipeline
transportation systems.
A list of all parts in the ISO 19345 series can be found on the ISO website.
© ISO 2017 – All rights reserved
ii

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oSIST prEN ISO 19345-2:2018
ISO/DIS 19345-2:2017(E)
Introduction
This document addresses the integrity of petroleum and natural gas pipelines through their entire life-
cycle, from design to eventual abandonment. For this reason, considerations relating to design,
construction, and abandonment have been included. This approach supports the development and
implementation of a holistic and integrated pipeline integrity management program that bridges
between life-cycle elements and thereby avoids compartmentalizing of the pipeline life-cycle into
essentially independent data and functional silos, which traditionally has been the case. The integrated
approach was developed on the basis of extensive research and examination of best practices and
results from pipeline integrity audits world-wide. This document is intended to be used by companies
that have not yet developed an official program or are developing a program for new pipelines. This
document can also be used to guide continual improvement of existing programs by both operating
companies and regulators to evaluate integrity management program effectiveness.
© ISO 2017 – All rights reserved
iii

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oSIST prEN ISO 19345-2:2018
DRAFT INTERNATIONAL STANDARD ISO/DIS 19345-2:2017(E)
Petroleum and natural gas industry — Pipeline
transportation systems — Pipeline integrity management
specification —
Part 2:
Full-life cycle integritymanagement for offshore pipeline
1. Scope
This document specifies requirements and gives recommendations on integrity management of pipeline
during the design, construction, commission, operation, maintenance and abandonment.
This document applies to offshore pipeline for transporting petroleum and natural gas. It applies to
rigid steel pipelines. It is not applicable to flexible pipelines, dynamic risers or those constructed from
other materials, such as glass-reinforced plastics.
An offshore pipeline system extends to:
 the first valve, flange or connection above water on platform or subsea mechanical connector with
subsea structure (i.e. manifold or dynamic riser);
 the connection point to the offshore installation (i.e. piping manifolds are not included);
 the first valve, flange, connection or isolation joint at a landfall, unless otherwise specified by the
onshore legislation.
The components mentioned above (valve, flange, connection, isolation joint) include also any pup
pieces, i.e. the offshore pipeline system extends to the weld beyond the pup piece, see in Figure 1.
© ISO 2017 – All rights reserved 1

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oSIST prEN ISO 19345-2:2018
ISO/DIS 19345-2:2017(E)
Key
1 First valve, flange, connection or isolation joint 7 Nearshore section
2 Connector point to subsea piping 8 Shore approach
3 Topside 9 Offshore section
4 Pipeline system 10 Onshore section
5 Pipeline subsea structure A Not covered by this document
6 First valve, flange, connection or isolation joint B Not covered by this document
Figure 1 — Extent of pipeline systems covered by this document
© ISO 2017 – All rights reserved
2

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oSIST prEN ISO 19345-2:2018
ISO/DIS 19345-2:2017(E)
2. Normative references
The following documents are referred to in the text in such a way that some or all of their content
constitutes requirements of this document. For dated references, only the edition cited applies. For
undated references, the latest edition of the referenced document (including any amendments) applies.
ISO 13623:2009, Petroleum and natural gas industries — Pipeline transporting system
ISO 15589-2, Petroleum, petrochemical and natural gas industries — Cathodic protection of pipeline
transportation systems — Part 2: Offshore pipelines
ISO 31000, Risk management — Principles and guidelines
IEC 31010, Risk assessment techniques
3. Terms, definitions and abbreviated terms
3.1 Terms and definitions
For the purposes of this document, the following terms and definitions apply.
ISO and IEC maintain terminological databases for use in standardization at the following addresses:
— ISO Online browsing platform: available at http://www.iso.org/obp
— IEC Electropedia: available at http://www.electropedia.org/
3.1.1
abandonment
activities associated with taking a pipeline permanently out of operation
Note 1 to entry: An abandoned pipeline cannot be returned to operation.
Note 2 to entry: Depending on the legislation this may require cover or removal.
3.1.2
anomaly
possible deviation from pipe material or weld soundness
Note 1 to entry: The identification of an indication of an anomaly may be generated by non-destructive inspection,
such as in-line inspection.
3.1.3
baseline assessment
first integrity assessment prior to or after operation
3.1.4
cathodic protection
corrosion control technique to prevent or reduce the corrosion of underground metal pipelines by
transferring an electrical current onto the pipe to achieve higher electrical potentials
3. 1.5
corrosion
deterioration of a material, usually a metal that results from an electrochemical reaction with its
environment
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3.1.6
crack
planar flaw, or linear discontinuity, with a sharp tip radius
3.1.7
critical consequence area
location where a pipeline release might have a significant adverse effect on public safety, property and
the environment
Note 1 to entry: The location and scope of critical consequence areas will change over time as human activity
data becomes available. The pipeline segments in CCAs are of particular interest in risk assessment and integrity
assessment evaluations and prioritizations.
3.1.8
deactivation
remove from service, may return to service after proper assessment, also defined as decommissioning
or suspension
3.1.9
deformation
change in shape of the pipe or component, such as a bend, buckle, dent, ovality, ripple, wrinkle, or any
other change that affects the roundness of the pipe or component’s original cross-section or
straightness of the pipe or component
3.1.10
defect
imperfection of a type or magnitude exceeding acceptable criteria
3.1.11
dent
depression which produces a disturbance in the curvature of the pipe wall, caused by contact with a
foreign body resulting in plastic deformation of the pipe wall
3. 1.12
design life
period for which the design basis is planned to remain valid
[SOURCE: ISO 13623:2009, 3.1.2]
3. 1.13
failure
event in which a component or system does not perform according to its operational requirements
3. 1.14
fitness for purpose
quantitative engineering evaluation that is performed to demonstrate the structural integrity of an in-
service component that can contain an imperfection, defect or damage
3. 1.15
gouge
surface damage to a pipeline caused by contact with a foreign object that has scraped (gouged) material
out of the pipe, resulting in a metal loss defect or imperfection
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3. 1.16
incident
unintentional release of gas or liquid due to the failure of a pipeline
Note1 to entry: Some regulatory authorities have defined incidents differently. In these cases, an incident may be
defined as: an event occurring on a pipeline for which operators shall make a report to the concerned regulatory
authority.
3. 1.17
in-line inspection
inspection of a pipe wall from the interior of the pipe using specialized tools
3. 1.18
integrity assessment
process that includes inspection and test of pipeline to obtain the pipe body’s information, combining
analysis of material and structure’s reliability, evaluating the safety state of the pipeline, so as to
determine the applicability of it
3. 1.19
integrity management program
documented program that specifies the practices used by the operating company to proactively manage
the safe, environmentally responsible, and reliable service of a pipeline system throughout its lifecycle
that incorporates a continual improvement process
3. 1.20
life extension
additional period of time beyond the original design or service life (but within the assessed remnant
life) for which permission to continue operating a pipeline system is granted by the regulatory bodies
Note 1 to entry: Life extension is considered as a modification to the design basis.
[SOURCE: ISO/TS 12747:2011, 3.7]
3. 1.21
magnetic flux leakage
type of in-line inspection technology in which a magnetic field is induced in the pipe wall between two
poles of a magnet
Note 1 to entry: Anomalies affect the distribution of the magnetic flux in the wall. The magnetic flux leakage
pattern is used to detect and characterize anomalies.
3. 1.22
management of change
process that systematically recognizes and communicates to the necessary parties changes of a
technical, physical, procedural, or organizational nature that can impact system integrity
3. 1.23
manufacturing defect
defect in the pipe body or coating created during the pipe or component manufacturing or coating
processes
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3. 1.24
maximum allowable operating pressure
maximum pressure at which the pipeline system, or parts thereof, is allowed to be operated and usually
determined by hydrostatic tests and a corresponding safety factor associated with the fluid transported
within a given location class area
3. 1.25
metal loss
pipe anomaly in which metal has been removed
Note 1 to entry: Metal loss is usually the result of corrosion, but gouging, manufacturing defects, or mechanical
damage can also result in metal loss.
3. 1.26
non-destructive testing
wide group of analysis techniques used to evaluate the properties of a material, component or system
without causing damage
Note 1 to entry: The terms non-destructive inspection (NDI) and non-destructive evaluation (NDE) are also
commonly used to describe this technology.
3. 1.27
offshore pipeline
part of a pipeline system that, except for pipeline risers, is located below the water surface at maximum
tide that use universally recognized offshore pipeline construction techniques.
Note 1 to entry: The pipeline may be resting wholly or intermittently on, or buried below, the seabed.
3. 1.28
operator
person or organization who owns or operates a pipeline system or facilities and is ultimately
responsible for the operation and integrity of the pipeline system
3. 1.29
pipeline integrity management
set of processes and procedures that proactively ensures incident-free transportation of fluids through
a pipeline system
3. 1.30
pipeline integrity management program
continual improvement closed-loop system using information technology to realize functions such as
data acquisition and integration, integrity and risk assessment, mitigation and repair activity and
maintenance decisions, with comprehensive management of change and continual review and
improvement processes
3. 1.31
pressure test
means of assessing the integrity of a new or existing pipeline that involves filling the pipeline with
water and pressurizing to a level reasonably in excess of the MAOP of the pipeline to demonstrate that
the pipeline is fit for service at the MAOP for a given time frame dependent on the identified integrity
hazards
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3. 1.32
risk
measure of loss, either qualitative or quantifiable, in terms of both the likelihood of incident occurrence
and the magnitude of the consequences of the incident occurrence
3. 1.33
risk assessment
systematic, analytical process in which potential hazards from pipeline system are proactively
identified, and the likelihood and consequences of potential adverse events are determined
3. 1.34
risk management
coordinated activities to direct and control an organization with regard to risk
[SOURCE: ISO Guide 73:2009, 2.1]
3. 1.35
safe operating pressure
pressure, calculated using remaining strength of corroded pipeline formulas, where all corroded
regions will withstand a pressure equal to a stress level of certain times of the MAOP according to
different safety factors or formula chosen
3. 1.36
service life
length of time over which the pipeline system is intended to operate
Note 1 to entry: Service life is considered the actual operational life to date, but may include any planned future
use of the line. Service life may be less or longer than design life.
[SOURCE: ISO/TS 12747:2011, 3.21]
3. 1.37
sizing accuracy
accuracy with which an anomaly dimension or characteristic is reported.
Note 1 to entry: Typically, accuracy is expressed by tolerance and certainty. As an example, depth sizing accuracy
for metal loss using NDT methods, such as an ILI tool, is commonly expressed as +/-10 % of the wall thickness
(the tolerance) and 80 % of the time (the certainty).
3. 1.38
third party damage
damage done to the pipeline as a result of activities by personnel not associated with the pipeline
3.1.39
threat
activity or condition than can adversely affect the pipeline system if not adequately controlled
[SOURCE: ISO/TS 12747:2011, 3.23]
3.2 Abbreviated terms
AC alternating current
CP cathodic protection
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CCA critical consequence area
CoF consequence of failure
DA direct assessment
ECDA external corrosion direct assessment
FFP fitness for purpose
GIS geographic information system
HIC hydrogen-induce cracking
ICDA internal corrosion direct assessment
ILI in-line inspection
IMP integrity management program
MAOP maximum allowable operating pressure
MFL magnetic flux leakage
NDT non-destructive testing
PIM pipeline integrity management
PoF probablity of failure
SCC stress corrosion cracking
SCCDA stress corrosion cracking direct assessment
SMYS specified minimum yield strength
SSC sulfide-stress cracking
4. General
4.1 Key principles
The operator uses integrity management programs (IMPs) to enable them to manage its pipeline
systems in a safe, environmentally responsible and reliable manner. An effective IMP anticipates and
mitigates or eliminates integrity issues before they lead to incidents or failures.
Key principles for an effective IMP are listed below:
a) Pipeline system integrity shall be viewed as a lifecycle approach from initial planning, design,
construction, operation and maintenance up to and including abandonment.
b) The operator shall provide adequate resources in terms of funds, equipment and competent
personnel to implement the IMP.
c) Clearly defined roles and responsibilities with clear communication processes are necessary.
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d) Document and records control and retention and data gathering are key mandatory elements that
enable informed decisions.
e) Performance measures of the IMP’s effectiveness should include both leading and lagging indicators
to identify trends and areas for continuous improvement.
f) An effective IMP is risk based and may be used to prioritize integrity related actives.
4.2 Integrity management program
4.2.1 General
The operator shall establish, implement, maintain and document an IMP and continually review its
adequacy and implementation and improve its effectiveness.
The pipeline IMP shall be part of a comprehensive management system which includes, as a minimum,
integration with safety and environment programs.
To facilitate the development and implementation of the initial IMP for a pipeline system, the operator
shall develop an integrity management plan, which includes a plan for initial data acquisition, threat
and hazard consequence identification and risk assessment, and improve it with integrity elements
introduced in 4.2.2. If applicable, the operator may also choose to incorporate mature IMP elements
from other pipeline systems, and customise them to their pipeline system or segment.
4.2.2 Introduction to IMP elements
The pipeline IMP shall address operators’ approach to the following elements, as illustrated in Figure 2:
a) Life cycle phases for integrity management:
Integrity shall be applied through the entire life cycle of pipeline, including:
1) feasibility;
2) design;
3) procurement;
4) installation;
5) transportation and storage;
6) construction;
7) pre-commissioning and commissioning;
8) handover;
9) operation and maintenance;
10) modification;
11) suspension/abandonment.
b) Pipeline integrity management process:
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As part of the continual improvement process, the inputs into these elements shall be routinely
updated, as required, to reflect the dynamic nature of pipeline systems:
1) data acquisition, review and integration;
2) risk assessment (threat, consequence, probability, CCAs);
3) inspection and monitoring;
4) integrity assessment;
5) mitigative activity;
6) performance measurement and improvement.
NOTE 1 Mitigation applied to residual threats is part of the monitoring and maintenance process.
NOTE 2 Understanding the pipeline’s integrity and threats in the context of the surrounding environment is
key to making informed integrity management decisions.
NOTE 3 Performance measurement can verify that the goals, targets and objectives of the integrity program
are being met and can be used during management reviews to identify improvement opportunities.
The following elements shall be developed for to the operational phase to ensure that adequate
management practices are in place to assess failures and manage and respond to emergencies:
1) failure assessment plan;
2) emergency response plan;
3) remaining life assessment plan.
NOTE 4 The failure assessment plan considers failure causes and contributing factors and provides critical
information to the IMP. The goal is to prevent reoccurrence of similar failures.
NOTE 5 The emergency response plan is designed to ensure that the operator is prepared to deal with
accidents and incidents in a timely manner to aid in the reduction of consequences. These accidents or
incidents can occur because the IMP did not foresee or was unable to effectively mitigate the threat.
NOTE 6 The remaining life assessment provides input into the economic viability assessment of the pipeline.
As the pipeline ages, the operational risks and mitigation costs increase until continuing the operation is no
longer viable.
c) Management elements:
The following elements shall form part of an IMP and may be written to encompass more than one
pipeline or system. These elements usually interact with other management systems within an
organization:
1) policy and commitment;
2) scope of the IMP;
3) organizational structure including key roles and responsibilities.
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The following mandatory elements predominately deal with information flow, providing the core of
the data system providing information for assessment and review. They are usually presented as
plans with procedures:
1) communication;
2) records and documents control;
3) management of change;
4) management review and audit;
5) training and competency.
Figure 2 — Pipeline integrity management program structure
4.3 Integrity management process elements
4.3.1 Data acquisition, review and integration
The first step in evaluating the potential threats for a pipeline system or segment is to define and gather
the necessary data and information that characterize the segments and the potential threats to that
segment. A plan for collection of historical data shall be established and maintained for the pipeline
system lifecycle. The operator shall perform the initial collection, review and integration of relevant
data and information from pipeline design, construction, operation, maintenance, patrolling and failure
investigation data. Data acquisition is needed to understand the condition of the pipe; identify the
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location-specific threats to its integrity; and understand the public, environmental, and operational
consequences of an incident.
4.3.2 Risk assessment
Risk analysis is an analytical process through which the operator considers the likelihood threats
occurring and the nature and severity of the resulting consequences.
Risk assessment shall be performed for all scenarios including low consequence—high likelihood and
critical consequence—low likelihood events. Every plausible failure mode shall be listed and assigned
risk evaluation. Where multiple consequences occur from a single failure mode, multiple assessments
are required.
The operator shall consider all of the threats and any interactive threats that can be applicable to its
system. It can be appropriate to consider risks in pipeline segmen
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