ISO/TS 16530-2:2014

Well integrity - Part 2: Well integrity for the operational phase

ISO/TS 16530-2:2014 provides requirements and methods to the oil and gas industry to manage well integrity during the well operational phase. The operational phase is considered to extend from handover of the well after construction, to handover prior to abandonment. This represents only the period during the life cycle of the well when it is being operated. ISO/TS 16530-2:2014 includes: ? A description of the processes required to assess and manage risk within a defined framework. The risk assessment process also applies when deviating from ISO/TS 16530-2:2014. ? The process of managing well integrity by operating wells in compliance with operating limits for all well types that are defined based on exposure of risk to people, environment, assets and reputation. The management of well integrity is supported by associated maintenance/monitoring plans, technical reviews and the management of change. ? The assessment of existing assets (wells / fields) in order to start the process of Well Integrity Management in accordance with ISO/TS 16530-2:2014. ? The handover process required when changing from one activity to another during the operational phase. ISO/TS 16530-2:2014 applies to all wells that are utilized by the oil and gas industry, regardless of their age, type or location.

Intégrité du puits — Partie 2: Intégrité du puits pour la phase opérationnelle

General Information

• Status: Withdrawn
• Publication Date: 05-Aug-2014
• Withdrawal Date: 05-Aug-2014
• ICS: 75.180.10 - Exploratory, drilling and extraction equipment
• Technical Committee: ISO/TC 67/SC 4 - Drilling and production equipment
• Drafting Committee: ISO/TC 67/SC 4/WG 4 - Production equipment
• Current Stage: 9599 - Withdrawal of International Standard
• Start Date: 18-Aug-2017
• Completion Date: 13-Dec-2025

Standards Content (Sample)

TECHNICAL ISO/TS
SPECIFICATION 16530-2
First edition
2014-08-15
Well integrity —
Part 2:
Well integrity for the operational
phase
Intégrité du puits —
Partie 2: Intégrité du puits pour la phase opérationnelle
Reference number
©
ISO 2014
© ISO 2014
All rights reserved. Unless otherwise specified, no part of this publication may be reproduced or utilized otherwise in any form
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ii © ISO 2014 – All rights reserved

Contents Page
Foreword .vi
Introduction .vii
1 Scope . 1
2 Normative references . 2
3 Terms, definitions and abbreviated terms . 2
4 Abbreviated terms . 8
5 Well integrity management system .10
5.1 Well integrity management .10
5.2 Well integrity management system.10
6 Well integrity policy and strategy .10
6.1 Well integrity policy .10
6.2 Well integrity strategy .10
7 Resources, roles, responsibilities and authority levels .11
7.1 Organizational structure .11
7.2 Competency .11
8 Risk assessment aspects of well integrity management .11
8.1 General .11
8.2 Risk assessment considerations for well integrity .12
8.3 Risk assessment techniques .15
8.4 Application of risk assessment in establishing monitoring, surveillance and
maintenance requirements .16
8.5 Application of risk assessment in the assessment of well integrity anomalies .17
8.6 Failure rate trending .17
9 Well barriers .18
9.1 General .18
9.2 Barrier philosophy .18
9.3 Well barrier envelopes .19
9.4 Well barrier element .19
9.5 Documenting of well barrier envelopes and well barrier elements .20
10 Well component performance standard .20
10.1 General .20
10.2 Acceptance criteria and acceptable leak rates .21
10.3 Measuring the leak rate .23
10.4 Effects of temperature .23
10.5 Direction of flow .23
10.6 Integrity of barriers to conduct well maintenance and repair .23
10.7 ESD/related safety systems .23
10.8 Well component operating procedure .24
11 Well operating and component limits .24
11.1 Well operating limits .24
11.2 Well load and tubular stress analysis .25
11.3 Further well-use review .26
11.4 End-of-life review .26
11.5 Management of change to the operating limits .26
12 Well monitoring and surveillance .26
12.1 General .26
12.2 Monitoring and surveillance frequency .27
12.3 Shut-in wells .27
12.4 Suspended wells .27
12.5 Visual inspection .28
12.6 Well logging .28
12.7 Corrosion monitoring.29
12.8 Cathodic protection monitoring .29
12.9 Erosion monitoring .30
12.10 Structural integrity monitoring .30
13 Annular pressure management .32
13.1 General .32
13.2 Management .32
13.3 Sources of annular pressure .32
13.4 Annulus pressure monitoring and testing .33
13.5 Frequency of monitoring tubing and annulus casing pressures .33
13.6 Identification of an annulus pressure source .34
13.7 Maximum allowable annular surface pressure .34
13.8 Maintaining annulus pressure within the thresholds .37
13.9 Review and change of MAASP and thresholds.37
14 Well handover.38
14.1 General .38
15 Well maintenance .39
15.1 General .39
15.2 Replacement parts .40
15.3 Frequency of maintenance.40
15.4 Component testing methods .40
15.5 Leak testing .42
16 Well integrity failure management .43
16.1 General .43
16.2 Integrity failure ranking and prioritization .43
16.3 Well failure model .43
17 Management of change .44
17.1 General .44
17.2 Integrity deviation process .45
17.3 Deviation from the well performance standard .45
17.4 MOC Process .45
18 Well records and well integrity reporting .46
18.1 General .46
18.2 Well records .47
18.3 Reports .47
19 Performance monitoring of well integrity management systems .48
19.1 Performance monitoring and continuous improvement .48
19.2 Performance review .48
19.3 Key performance indicator monitoring .50
20 Compliance audit .51
20.1 General .51
20.2 Audit process .52
Annex A (informative) Well integrity roles and responsibilities chart .53
Annex B (informative) Example of competency matrix .54
Annex C (informative) Barrier element acceptance table .55
Annex D (informative) Well barrier schematic .56
Annex E (informative) Example — Performance standard for well safety critical elements .58
Annex F (informative) Well barrier elements, functions and failure modes .59
Annex G (informative) Example of possible well leak paths .62
iv © ISO 2014 – All rights reserved

Annex H (informative) Example of leak testing gas lift valves .64
Annex I (informative) Leak rate determination calculations .66
Annex J (informative) Well operating limits .69
Annex K (informative) MAASP calculations .71
Annex L (informative) Example — A change in MAASP calculation .79
Annex M (normative) Information required of well handover .81
Annex N (informative) Function testing by analysing hydraulic signature .84
Bibliography .86
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 1. 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 2 (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 WTO principles in the Technical Barriers
to Trade (TBT) see the following URL: Foreword - Supplementary information
The committee responsible for this document is ISO/TC 67, Materials, equipment and offshore structures
for petroleum, petrochemical and natural gas industries, Subcommittee SC 4, Drilling and production
equipment.
ISO/TS 16530 consists of the following parts, under the general title Well integrity:
— Part 2: Well integrity for the operational phase
The following parts are under preparation:
— Part 1: Life cycle governance manual
vi © ISO 2014 – All rights reserved

Introduction
This Technical Specification has been developed by producing operating companies for oil and gas, and
is intended for use in the petroleum and natural gas industry worldwide. This Technical Specification
is intended to give requirements and information to the Well Operator on managing well integrity for
the operational phase. Furthermore, this Technical Specification addresses the minimum compliance
requirements for the Well Operator, in order to claim conformity with this Technical Specification.
It is necessary that users of this Technical Specification are aware that requirements above those outlined
in this Technical Specification can be needed for individual applications. This Technical Specification is
not intended to inhibit or replace legal requirements; it is in addition to the legal requirements; where
there is a conflict the legal requirement always takes precedence. This can be particularly applicable
where there is innovative or developing technology, with changes in field or well design operating
philosophy.
This Technical Specification addresses the process of managing well integrity by assuring compliance
to the specified operating limits for identified well types, that are defined based on exposure of risk
to people, environment, assets and reputation, supported by associated well maintenance/monitoring
plans, technical reviews and management of change.
The following terminology is used in this Technical Specification.
a) The term “shall” or “must” denotes a minimum requirement in order to conform to this Technical
Specification.
b) The term “should” denotes a recommendation or that which is advised but not required in order to
conform to this Technical Specification.
c) The term “may” is used to indicate a course of action permissible within the limits of the document.
d) The term “consider” is used to indicate a suggestion or to advise.
e) The term “can” is used to express possibility or capability.
TECHNICAL SPECIFICATION ISO/TS 16530-2:2014(E)
Well integrity —
Part 2:
Well integrity for the operational phase
IMPORTANT — The electronic file of this document contains colours which are considered to be
useful for the correct understanding of the document. Users should therefore consider printing
this document using a colour printer.
1 Scope
This Technical Specification provides requirements and methods to the oil and gas industry to manage
well integrity during the well operational phase.
The operational phase is considered to extend from handover of the well after construction, to handover
prior to abandonment. This represents only the period during the life cycle of the well when it is being
operated and is illustrated in Figure 1.
The scope of the Technical Specification includes:
— A description of the processes required to assess and manage risk within a defined framework. The
risk assessment process also applies when deviating from this Technical Specification.
— The process of managing well integrity by operating wells in compliance with operating limits
for all well types that are defined based on exposure of risk to people, environment, assets and
reputation. The management of well integrity is supported by associated maintenance/monitoring
plans, technical reviews and the management of change.
— The assessment of existing assets (wells / fields) in order to start the process of Well Integrity
Management in accordance with this technical specification.
— The handover process required when changing from one activity to another during the operational
phase.
The scope of the Technical Specification applies to all wells that are utilized by the oil and gas industry,
regardless of their age, type or location.
The scope of the Technical Specification does NOT apply to:
— The periods during well intervention or work-over activities but it DOES include the result of the
intervention and any impact that this can have to the well envelope and the associated well barriers.
— The equipment that is required or used outside the well envelope for a well intervention such as
wire-line or coiled tubing or a pumping package.
Well
Detailed
Well
Well
Construction
Well
Abandonment
Planning
Design
Well
Hand-
over
Well
Well
Intervention
or Workover
Operational
Phase
Well Well
Hand- Hand-
over over
Figure 1 — Illustration of the scope of this Technical Specification
2 Normative references
The following documents, in whole or in part, are normatively referenced in this document and are
indispensable for its application. For dated references, only the edition cited applies. For undated
references, the latest edition of the referenced document (including any amendments) applies.
ISO 10417:2004, Petroleum and natural gas industries — Subsurface safety valve systems — Design,
installation, operation and redress
API RP 14H, Recommended Practice for Installation, Maintenance and Repair of Surface Safety Valves and
Underwater Safety Valves Offshore, Fifth Edition
3 Terms, definitions and abbreviated terms
For the purposes of this document, the following terms and definitions apply.
3.1
A-annulus
designation of annulus between the production tubing and production casing
[SOURCE: API RP 90, modified]
3.2
abandoned well
permanent subsurface isolation of the well
3.3
ambient pressure
pressure external to the wellhead
Note 1 to entry: In the case of a surface wellhead, the pressure is zero psig. In the case of a subsea wellhead, it is
equal to the hydrostatic pressure of seawater at the depth of the subsea wellhead, in psig.
[SOURCE: API RP 90, modified]
2 © ISO 2014 – All rights reserved

3.4
anomaly
condition that differs from what is expected or typical, or which differs from that predicted by a
theoretical model
3.5
B-annulus
designation of annulus between the production casing and the next outer casing
Note 1 to entry: The letter designation continues in sequence for each outer annular space encountered between
casing strings, up to and including the surface casing and conductor casing strings.
[SOURCE: API RP 90, modified]
3.6
breaking of containment
breaking into the containment system of integrity or barrier envelope
3.7
competency
ability of an individual to perform a job properly through a combination of training, demonstrated skills
and accumulated experience
3.8
component
mechanical part, including cement, used in the construction of a well
3.9
conductor casing
element that provides structural support for the well, wellhead and completion equipment, and often for
hole stability for initial drilling operations
Note 1 to entry: This casing string is not designed for pressure containment, but upon completion of the well, it
may have a casing head; therefore, it can be capable of containing low annular pressures. For subsea and hybrid
wells, the low pressure subsea wellhead is normally installed on this casing string.
[SOURCE: API RP 90, modified]
3.10
consequence
expected effect of an event that occurs
3.11
deep-set
below or close to the production packer, or at the cap rock of a reservoir to isolate the production tubing
or casing from the producing reservoir
3.12
deviation
departure from a standard
3.13
double-block and bleed principle
operation with two valves or seals, in series, or a valve and a blind cap in all relevant, utilized flow paths
into and out of the well that are not connected to a closed system
3.14
failure
loss of intended function
3.15
failure mode
description of the method of failure
3.16
failure modes and effects analysis
FMEA
procedure used in design, development and operations management for the analysis of potential failure
modes within a system for classification of the severity and likelihood of the failures
3.17
failure mode, effects, and criticality analysis
FMECA
extension of FMEA (3.16) that in addition includes an analysis of the criticalities to evaluate the
seriousness of the consequences of a failure versus the probability of its occurrence
3.18
fault
abnormal, undesirable state of a system element (e.g. entire subsystem, assembly, component) induced
by the presence of an improper command or absence of a proper one, or by a failure
Note 1 to entry: All failures cause faults, not all faults are caused by failure.
3.19
flow-wetted
any surface that is exposed to fluids coming from a pressure source for that fluid
3.20
handover
act or process of transferring responsibility for operating a well from one competent party to another,
including both custody to operate (certificate) and the requisite data and documents which describe the
well construction
3.21
hazard
source of potential harm or a situation with a potential to cause loss (any negative consequence)
[SOURCE: API RP 90, modified]
3.22
hybrid well
well drilled with a subsea wellhead and completed with a surface casing head, a surface tubing head, a
surface tubing hanger, and a surface Christmas tree
Note 1 to entry: A hybrid well can have either one (single-bore production riser) casing string or two (dual-bore
production riser) casing strings brought up from the subsea wellhead and tied back to the surface equipment.
These wells are typically located on floating production platforms, such as spars or TLPs.
[SOURCE: API RP 90, modified]
3.23
impairment
state of diminished ability to perform a function, but not yet failed
3.24
inflow testing
use of the tubing or casing pressure to perform leak testing
3.25
intervention
operation to enter the well through the Christmas tree
4 © ISO 2014 – All rights reserved

3.26
leak
unintended and, therefore, undesired movement of fluids, either to or from, a container or a fluid
containing system
3.27
casing/liner
casing string with its uppermost point inside and near the bottom end of a previous casing string using
a liner hanger
3.28
major hazard
hazard (3.21) with a potential for causing major accidents, i.e. involving fatality due to fire or explosion,
major pollution, multiple fatalities, or severe damage to the installation
3.29
maximum allowable annulus surface pressure
MAASP
P
MAASP
greatest pressure that an annulus can contain, as measured at the wellhead, without compromising the
integrity of any element of that annulus, including any exposed open-hole formations
3.30
the operational phase
is considered to extend from handover of the well after construction, to handover prior to abandonment,
indicating the life cycle of the well while being operated
3.31
Well Operator-imposed annulus pressure
casing pressure that is Well Operator-imposed for purposes such as gas lift, water injection, thermal
insulation, etc
[SOURCE: API RP 90, modified]
3.32
performance standard
statement, which can be expressed in qualitative or quantitative terms as appropriate, of the performance
required of a safety-critical element in order to ensure the safety and integrity of the installation
3.33
pressure test
application of a pressure from an external source (non-reservoir pressure) to ascertain the mechanical
and sealing integrity of a component
3.34
primary well barrier
first well barrier envelope that the produced and/or injected fluids contact and that is in-place and
functional during well operations
3.35
production casing
innermost string of casing in the well
Note 1 to entry: Production fluids enter the casing below the production packer and continue to the surface through
the production string. At a minimum, the production casing is rated for the maximum anticipated pressure that
can be encountered from the production zone.
[SOURCE: API RP 90, modified]
3.36
production riser
on fixed platforms, the casing strings rising from the seafloor to the wellhead or, on hybrid wells, the
casing strings attached to the subsea wellhead rising from the seafloor to the surface wellhead
[SOURCE: API RP 90, modified]
3.37
production string
completion string
string consisting primarily of production tubing, but also including additional components such as the
surface-controlled subsurface safety valve (SCSSV), gas lift mandrels, chemical injection and instrument
ports, landing nipples, and packer or packer seal assemblies
Note 1 to entry: The production string is run inside the production casing and used to conduct production fluids
to the surface.
[SOURCE: API RP 90, modified]
3.38
production tubing
tubing that is run inside the production casing and used to convey produced fluids from the hydrocarbon-
bearing formation to the surface
Note 1 to entry: Tubing can also be used for injection. In some hybrid wells, for example, tubing is used as a conduit
for gas for artificial lift below a mudline pack-off tubing hanger to isolate the gas-lift pressure from the production
riser.
[SOURCE: API RP 90, modified]
3.39
reliability
probability that equipment can perform a specified function under stated conditions for a given period
of time
3.40
risk
combination of the consequences of an event and the associated likelihood of its occurrence
3.41
risk assessment
systematic analysis of the risks from activities and a rational evaluation of their significance by
comparison against predetermined standards, target risk levels or other risk criteria
Note 1 to entry: Risk assessment is used to determine risk management priorities.
3.42
safety critical element
part of the installation or plant that is essential to maintain the safety and integrity of the installation
Note 1 to entry: This includes any item that is intended to prevent or limit the effect of a major hazard or which,
upon failure, can cause or contribute substantially to a major hazard affecting the safety or integrity of the
installation.
Note 2 to entry: Safety-critical elements include measures for prevention, detection, control and mitigation
(including personnel protection) of hazards.
Note 3 to entry: Within the context of this Technical Specification, an installation is considered as a well.
6 © ISO 2014 – All rights reserved

3.43
secondary well barrier
second set of barrier elements that prevent flow from a source
[SOURCE: API RP 90, modified]
3.44
shut-in well
well with one or more valve(s) closed in the direction of flow
3.45
subsea well
well completed with a subsea wellhead and a subsea tree
[SOURCE: API RP 90, modified]
3.46
subsea wellhead
wellhead that is installed at or near the seabed
3.47
surface casing
casing that is run inside the conductor casing to protect shallow water zones and weaker formations
and may be cemented within the conductor string and is often cemented back to the mud-line or surface
Note 1 to entry: The surface wellhead is normally installed on this string for surface wells.
[SOURCE: API RP 90]
3.48
suspended well
well that has been isolated from the producing reservoir via a deep-set down-hole isolation device
(mechanical or cement plug)
Note 1 to entry: Components above the isolation device are no longer considered flow wetted.
3.49
sustained annulus pressure (SAP)
pressure in an annulus that
a) rebuilds when bled down;
b) is not caused solely by temperature fluctuations; and
c) is not a pressure that has been imposed by the Well Operator
[SOURCE: API RP 90, modified]
3.50
thermally induced annulus pressure
pressure in an annulus generated by thermal expansion or contraction of trapped fluids
[SOURCE: API RP 90, modified]
3.51
verification
examination, testing, audit or review to confirm that an activity, product or service is in accordance
with specified requirements
3.52
well barrier element
one or several dependent components that are combined to form a barrier envelope that, in combination,
prevent uncontrolled flow of fluids within or from a well
3.53
well barrier envelope
combination of one or several well barrier elements that together constitute a method of containment of
fluids within a well that prevent uncontrolled flow of fluids within, or out of, a well
3.54
well integrity
containment and the prevention of the escape of fluids (i.e. liquids or gases) to subterranean formations
or surface
3.55
well integrity management
See 5.1
3.56
well inventory
portfolio of wells that are not abandoned
3.57
Well Operator
company that has responsibility for operating the well
3.58
well operational phase
portion of the well’s life cycle starting at the handover of the well after construction, until the well’s
permanent abandonment
Note 1 to entry: This includes production, injection, observation, closed-in and suspended well statuses.
Note 2 to entry: Well intervention activities, either rig based or rig-less, that involve breaking containment at the
Christmas tree or wellhead are not part of the well operational phase.
3.59
well operating limits
combination of criteria that are established by the Well Operator to determine acceptable well integrity
performance for the well’s life
3.60
well status
well’s current operational function i.e. flowing, closed in, suspended, undergoing construction or
abandoned
4 Abbreviated terms
ALARP as low as reasonably practicable
API American Petroleum Institute
ASV annulus safety valve
BOP blow out preventer
BS&W base sediment & water
DASF drilling adaptor spool flange
DHSV Down-hole safety valve
ESD emergency shut-down
EVP emergency valve pilot
8 © ISO 2014 – All rights reserved

FMEA failure modes and effects analysis
FMECA failure-mode and effects and criticality analysis
FS formation strength
BOP annulus safety valve
BS&W blow out preventer
NORSOK Norsk Sokkels Konkurranseposisjon
NPT national pipe thread
OCP observed casing pressure
OD outer diameter
OEM original equipment manufacturer
QRA quantifiable risk assessment
RACI responsible/accountable/consulted/informed
ID internal diameter
KPI key performance indicator
MAASP maximum allowable annular surface pressure
MOC management of change
ROV remotely-operated vehicle
SCE safety critical element
SAP sustained annulus pressure
SF safety factor
SCSSV surface controlled subsurface safety valve
SSCSV subsurface controlled subsurface safety valve
SSSV sub surface safety valve
SSV surface safety valve
TOC top of cement
WBE well barrier element
WIMS well integrity management system
WOE well operating limits
NOTE NORSOK standards are developed by the Norwegian petroleum industry to ensure adequate
safety, value adding and cost effectiveness for petroleum industry developments and operations.
5 Well integrity management system
5.1 Well integrity management
The management of well integrity is a combination of technical, operational and organizational processes
to ensure a well’s integrity during the operating phase of the life cycle.
5.2 Well integrity management system
The Well Operator shall have an approved well integrity management system (WIMS) that is applied to
all wells under their responsibility, i.e. the well inventory.
As a minimum, the following elements shall be addressed:
a) well integrity policy and strategy;
b) resources, roles, responsibilities and authority levels;
c) risk assessment aspects of well integrity management;
d) well barriers;
e) well component performance standards;
f) well operating limits;
g) well monitoring and surveillance;
h) annular pressure management;
i) well handover;
j) well maintenance;
k) well integrity failure management;
l) management of change;
m) well records and well integrity reporting;
n) performance monitoring of well integrity management systems;
o) compliance audit.
6 Well integrity policy and strategy
6.1 Well integrity policy
The Well Operator shall have a policy defining its commitments and obligations to safeguard health,
environment, assets and reputation by establishing and preserving well integrity. This well integrity
policy shall be endorsed at a senior level within the Well Operator organization.
The Well Operator well integrity management system (WIMS) shall clearly indicate how the policy is
interpreted and applied to well integrity.
6.2 Well integrity strategy
The Well Operator shall define the high level strategic measures to which it is committing in order to
achieve the requirements of the asset (well) integrity policy.
10 © ISO 2014 – All rights reserved

Such strategic measures may include an outline of how the Well Operator establishes
— business plans and priorities,
— resourci
...