SIST EN ISO 13628-1:2025

SLOVENSKI STANDARD
01-april-2025
Naftna in plinska industrija, vključno z nizkoogljično energijo - Načrtovanje in
upravljanje proizvodnje v podmorskih sistemih - 1. del: Splošne zahteve in
priporočila (ISO 13628-1:2025)
Oil and gas industries including low carbon energy - Design and operation of subsea
production systems - Part 1: General requirements and recommendations (ISO 13628-
1:2025)
Öl- und Gasindustrie einschließlich kohlenstoffarmer Energieträger - Auslegung und
Betrieb von Unterwasser-Fördersystemen - Teil 1: Allgemeine Anforderungen und
Empfehlungen (ISO 13628-1:2025)
Industries du pétrole et du gaz, y compris les énergies à faible teneur en carbone -
Conception et exploitation des systèmes de production immergés - Partie 1: Exigences
générales et recommandations (ISO 13628-1:2025)
Ta slovenski standard je istoveten z: EN ISO 13628-1:2025
ICS:
75.180.10 Oprema za raziskovanje, Exploratory, drilling and
vrtanje in odkopavanje extraction equipment
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

EN ISO 13628-1
EUROPEAN STANDARD
NORME EUROPÉENNE
February 2025
EUROPÄISCHE NORM
ICS 75.180.10 Supersedes EN ISO 13628-1:2005, EN ISO 13628-
1:2005/A1:2010
English Version
Oil and gas industries including low carbon energy -
Design and operation of subsea production systems - Part
1: General requirements and recommendations (ISO
13628-1:2025)
Industries du pétrole et du gaz, y compris les énergies Öl- und Gasindustrie einschließlich kohlenstoffarmer
à faible teneur en carbone - Conception et exploitation Energieträger - Auslegung und Betrieb von
des systèmes de production immergés - Partie 1: Unterwasser-Fördersystemen - Teil 1: Allgemeine
Exigences générales et recommandations (ISO 13628- Anforderungen und Empfehlungen (ISO 13628-
1:2025) 1:2025)
This European Standard was approved by CEN on 29 March 2024.

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, France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta, Netherlands, Norway,
Poland, Portugal, Republic of North Macedonia, Romania, Serbia, Slovakia, Slovenia, Spain, Sweden, Switzerland, Türkiye 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
© 2025 CEN All rights of exploitation in any form and by any means reserved Ref. No. EN ISO 13628-1:2025 E
worldwide for CEN national Members.

Contents Page
European foreword . 3

European foreword
This document (EN ISO 13628-1:2025) has been prepared by Technical Committee ISO/TC 67 "Oil and
gas industries including lower carbon energy" in collaboration with Technical Committee CEN/TC 12
“Oil and gas industries including lower carbon energy” 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 August 2025, and conflicting national standards shall
be withdrawn at the latest by August 2025.
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.
This document supersedes EN ISO 13628-1:2005, EN ISO 13628-1:2005/A1:2010.
Any feedback and questions on this document should be directed to the users’ national standards
body/national committee. A complete listing of these bodies can be found on the CEN website.
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, France, Germany, Greece, Hungary, Iceland,
Ireland, Italy, Latvia, Lithuania, Luxembourg, Malta, Netherlands, Norway, Poland, Portugal, Republic of
North Macedonia, Romania, Serbia, Slovakia, Slovenia, Spain, Sweden, Switzerland, Türkiye and the
United Kingdom.
Endorsement notice
The text of ISO 13628-1:2025 has been approved by CEN as EN ISO 13628-1:2025 without any
modification.
International
Standard
ISO 13628-1
Third edition
Oil and gas industries including
2025-01
low carbon energy — Design and
operation of subsea production
systems —
Part 1:
General requirements and
recommendations
Industries du pétrole et du gaz, y compris les énergies à faible
teneur en carbone — Conception et exploitation des systèmes de
production immergés —
Partie 1: Exigences générales et recommandations
Reference number
ISO 13628-1:2025(en) © ISO 2025

ISO 13628-1:2025(en)
© ISO 2025
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
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or ISO’s member body in the country of the requester.
ISO copyright office
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CH-1214 Vernier, Geneva
Phone: +41 22 749 01 11
Email: copyright@iso.org
Website: www.iso.org
Published in Switzerland
ii
ISO 13628-1:2025(en)
Contents Page
Foreword .v
Introduction .vi
1 Scope . 1
2 Normative references . 1
3 Terms, definitions and abbreviated terms . 1
3.1 Terms and definitions .1
3.2 Abbreviated terms .3
4 Subsea production system . 4
4.1 General .4
4.2 System configuration .4
4.3 Overview of API 17 series documents by categories .5
4.3.1 System level documents . .5
4.3.2 Subsea hardware (wellheads, trees, manifolds, structures, connectors, and
pumps) .6
4.3.3 Flowlines and risers .7
4.3.4 Control systems .7
4.3.5 Intervention systems .8
5 Systems engineering . 8
5.1 General .8
5.2 Systems engineering process .9
5.3 Subsea system production assurance and reliability management .10
6 Equipment design requirements .11
6.1 Design basis.11
6.2 Safety.11
6.2.1 General .11
6.2.2 Safety strategy . 12
6.2.3 Safety by design . 12
6.3 Barrier and isolation considerations . 12
6.3.1 Barrier philosophy . 12
6.3.2 Barrier requirements .14
6.3.3 Subsea isolation philosophy .14
6.4 Materials . 15
6.5 Structural analysis .16
6.5.1 General .16
6.5.2 Wellhead, tree, and C/WO riser system analysis .16
6.6 Pumps, piping, and valves .16
6.7 Dropped objects and fishing gear loads .17
6.8 Lifting components, padeyes, and unpressurized structural components .17
6.9 Colours and marking .17
6.10 Tolerance evaluation .17
6.11 Design for installation .18
6.12 Environmental considerations .18
6.13 Evaluation of subsea pressure testing limitations .18
6.14 Design for intervention .19
7 Technology management guidance . 19
7.1 Technology development and qualification .19
7.2 Obsolescence management . 20
8 Manufacture, assembly, testing, installation, and commissioning guidance .21
8.1 Manufacture.21
8.2 Assembly .21
8.3 Testing .21
8.3.1 General .21

iii
ISO 13628-1:2025(en)
8.3.2 Inspection and test plans . 22
8.4 Transportation, preservation, and storage . 22
8.5 Load-out and installation . 23
8.6 Commissioning/systems completion .24
9 Operations guidance .24
9.1 Integrity management .24
9.1.1 Condition monitoring .24
9.1.2 Reliability data collection/reporting . 25
9.1.3 Subsea production system maintenance . 25
9.2 Production management . 25
10 Well intervention guidance .26
11 Decommissioning guidance .26
Annex A (informative) Systems engineering processes .28
Bibliography .29

iv
ISO 13628-1:2025(en)
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 document 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).
ISO draws attention to the possibility that the implementation of this document may involve the use of (a)
patent(s). ISO takes no position concerning the evidence, validity or applicability of any claimed patent
rights in respect thereof. As of the date of publication of this document, ISO had not received notice of (a)
patent(s) which may be required to implement this document. However, implementers are cautioned that
this may not represent the latest information, which may be obtained from the patent database available at
www.iso.org/patents. ISO shall not be held responsible for identifying any or all such patent rights.
Any trade name used in this document is information given for the convenience of users and does not
constitute an endorsement.
For an explanation of the voluntary nature of standards, 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 www.iso.org/iso/foreword.html.
This document was prepared by Technical Committee ISO/TC 67, Oil and gas industries including lower carbon
energy, Subcommittee SC 4, Drilling, production and injection equipment, in collaboration with the European
Committee for Standardization (CEN) Technical Committee CEN/TC 12, Oil and gas industries including lower
carbon energy, in accordance with the Agreement on technical cooperation between ISO and CEN (Vienna
Agreement).
This third edition cancels and replaces the second edition (ISO 13628-1:2005), which has been technically
revised. It also incorporates the Amendment ISO 13628-1:2005/Amd 1:2010.
The main changes are as follows:
— ISO 13628-1 has been fully re-written compared to the 2005 edition of the document;
— ISO 13628-1 has been aligned with API RP 17A and is now a technically equivalent document.
A list of all parts in the ISO 13628 series can be found on the ISO website.
Any feedback or questions on this document should be directed to the user’s national standards body. A
complete listing of these bodies can be found at www.iso.org/members.html.

v
ISO 13628-1:2025(en)
Introduction
This document has been prepared to provide general requirements and recommendations for the user to the
various areas requiring consideration during development of a subsea production system for the petroleum
and natural gas industries. The requirements and guidance in this document are intended to complement
engineering judgement and facilitate the decision process.

vi
International Standard ISO 13628-1:2025(en)
Oil and gas industries including low carbon energy — Design
and operation of subsea production systems —
Part 1:
General requirements and recommendations
1 Scope
This document provides general requirements and recommendations for the development and operation
of subsea production/injection systems, from the concept development phase to decommissioning and
abandonment.
Flexible pipe standards form part of the API 17-series of documents (see 4.3.3); however, this document
th
(technically equivalent to API RP 17A 6 edition) does not generally cover flowlines/pipelines or production/
injection risers (associated with flowlines/pipelines). These components form part of a complete subsea
production system (SPS), as shown in Figure 1.
2 Normative references
There are no normative references in this document.
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 terminology databases for use in standardization at the following addresses:
— ISO Online browsing platform: available at https:// www .iso .org/ obp
— IEC Electropedia: available at https:// www .electropedia .org/
3.1.1
barrier
element forming part of a pressure-containing envelope that is designed to prevent unintentional flow of
production/injected fluids, particularly to the external environment
3.1.2
factory acceptance test
FAT
test conducted to verify that the specified requirements for a product have been fulfilled
3.1.3
first article
first of a product produced using the “normal processes” as will be used to make multiple numbers of the
same product
EXAMPLE The first of a new design of SCM manufactured on a production line and intended for use in the field.
Note 1 to entry: As distinct from a prototype, a first article should accurately represent all aspects and functionality
of the production-model product.

ISO 13628-1:2025(en)
The “normal processes” typically includes the standard design, procurement, manufacture, QA/QC, and testing
processes, as would be used in the production of a production model/production product.
Such a product is suitable for normal use.
First article products are often subjected to comprehensive verification testing (3.1.9) and validation testing (3.1.8), as
well as subsequent strip-down and inspection for evidence of component deterioration and/or loss of functionality.
3.1.4
high-pressure high-temperature
HPHT
any environment above 103,5 MPa (15 000 psi) working pressure and/or operating above 177 °C (350 °F)
3.1.5
interchangeability test
ICT
test conducted to verify that the interchangeability requirements of “identical” products [including products
of like design, with respect to the relevant interface(s)], which may be interfaced with other mating products
at the installation site, have been fulfilled
3.1.6
life cycle
series of identifiable stages through which an item goes, from its conception to disposal
3.1.7
pilot
first of a product used for an extended period in the intended service in order to validate a concept or
process, prior to the manufacture and deployment of additional similar products
EXAMPLE The Troll Pilot subsea separation system.
Note 1 to entry: Similar to a prototype, a pilot is usually a “one-off” and therefore is often not produced using the exact
same processes as will be used to make the actual production model of a product (of which multiple numbers are
typically produced).
However, unlike a prototype, a pilot should accurately represent all aspects and functionality of the intended
production model product in order to ensure a valid test and to be suitable for use in the field.
Based on the results gained from the extended field testing of a pilot, it is not uncommon for the actual production
model to be different from the pilot in some aspects.
3.1.8
validation testing
test conducted to confirm that the requirements for a specific intended use or application of a product have
been fulfilled
3.1.9
verification testing
test conducted to confirm that the specified requirements for a product have been fulfilled
3.1.10
qualification
process to demonstrate the ability to fulfil specified requirements
EXAMPLE Auditor qualification process, material qualification process.
Note 1 to entry: The term “qualified” is used to designate the corresponding status.
Note 2 to entry: Qualification can concern persons, products, processes or systems.

ISO 13628-1:2025(en)
3.1.11
validation
confirmation, through the provision of objective evidence, that the requirements for a specific intended use
or application have been fulfilled
Note 1 to entry: The term “validated” is used to designate the corresponding status.
Note 2 to entry: The use conditions for validation can be real or simulated.
3.1.12
verification
confirmation, through the provision of objective evidence, that specified requirements have been fulfilled
Note 1 to entry: The term “verified” is used to designate the corresponding status.
Note 2 to entry: Confirmation can comprise activities such as:
— performing alternative calculations;
— comparing a new design specification with a similar proven design specification;
— undertaking tests and demonstrations;
— reviewing documents prior to issue.
3.2 Abbreviated terms
BOP blowout preventer
CRA corrosion-resistant alloy
C/WO completion/workover
EDP emergency disconnect package
FMEA failure modes and effects analysis
FMECA failure mode, effects, and criticality analysis
HAZOP hazard and operability study
HIPPS high integrity pressure protection system
HSE health, safety and environment
IWOCS installation workover control system
LMRP lower marine riser package
LRFD load and resistance factored design
MODU mobile offshore drilling unit
MPFM multiphase flow meter
OEM original equipment manufacturer
OREDA offshore and onshore reliability data
PLEM pipeline end manifold
QRA quantitative risk assessment

ISO 13628-1:2025(en)
ROT remotely operated tool
ROV remotely operated vehicle
SCM subsea control module
SUT subsea umbilical termination
USV underwater safety valve
VIV vortex induced vibration
WSD working stress design
4 Subsea production system
4.1 General
A complete subsea production/injection system comprises several subsystems necessary to produce
hydrocarbons from one or more subsea wells and transfer them to a processing/host facility located offshore
(fixed, floating, or subsea) or onshore, or to inject water/gas via subsea facilities and/or wells (as shown in
Figure 1).
NOTE The term “subsea production system” is used generically throughout this document to describe both
production and injection systems.
Subsea production systems range in complexity from a single satellite well linked to an offshore or onshore
installation to several wells comingled in a subsea manifold producing to a fixed, floating, or onshore facility.
Subsea production systems can be used to produce from shallow-water or deepwater reservoirs. Deepwater
conditions can inherently dictate development of a field by means of a subsea production system, since fixed
structures such as a steel-piled jacket can be either technically infeasible or uneconomical due to the water depth.
Subsea equipment may be used for the injection of water/gas into various formations for disposal and/or to
provide pressure maintenance to the reservoir, and/or for gas lifting operations.
4.2 System configuration
The elements of the subsea production or injection system may be configured in numerous ways, as dictated
by the specific requirements and the field development strategy. For a description of the various components,
assemblies, and subsystems that can be combined to form a complete subsea system, refer to API 17TR13.
Figure 1 provides an overview of a basic subsea system.

ISO 13628-1:2025(en)
Key
1 LMRP 10 XT
2 marine riser 11 wellhead
3 flex joint 12 jumper
4 BOP 13 HCM
5 workover riser 14 HIPPS
6 stress joint 15 manifold
7 EDP 16 flowline
8 ERP/well control module 17 process station
9 SCM
Figure 1 — Basic subsea systems
4.3 Overview of API 17 series documents by categories
4.3.1 System level documents
Subsea documents that address system requirements include the following.
— API RP 17A provides general requirements and recommendations for the development of subsea
production systems, from the design phase to decommissioning and abandonment. API 17A also provides
guidance to other parts in the API 17 series and related documents.
NOTE API RP 17A is technically equivalent to this document.

ISO 13628-1:2025(en)
— API RP 17N provides recommended practice for subsea production system reliability and technical
risk management. Reliability is critical to subsea production system design and operation. API RP 17N
provides a comprehensive approach to help ensure that reliability needs are achieved with subsea
systems. It is broadly referenced in the deepwater technical community as a foundation document for
addressing reliability.
— API RP 17O provides recommended practice for high integrity pressure protection systems (HIPPS). It
establishes criteria for HIPPS that are seeing increased utilization in industry as a means to safely provide
overall system pressure capability while restricting the section that requires full shut-in pressure rating
to a segment that is close to the source.
— API RP 17Q provides recommended practice for subsea equipment qualification. It provides guidance on
relevant qualification methods that may be applied to facilitate subsea project execution.
— API RP 17V provides recommended practice for analysis, design, installation, and testing of safety
systems for subsea applications. It provides a comprehensive treatment of the requirements for safety
systems necessary for a variety of subsea applications.
— API 17TR5 addresses avoidance of blockages in subsea production control and chemical injection
systems. It also includes requirements and gives recommendations for the design and operation of
subsea production systems with the aim of preventing blockages in control and production chemical
fluid conduits and associated connectors/fittings.
— API 17TR6 addresses attributes of production chemicals in subsea production systems. Production
chemicals delivered to a subsea production system via a chemical injection system can be complex
formulations that have a wide range of chemical and physical properties. In service, the production
chemicals can come into contact with other fluids, metallic and polymeric materials, and a range of
physical conditions related to temperature and pressure. API 17TR6 was developed with the objective
of minimizing the risk of a production chemical not being delivered at the required volumetric rate due
to inadequate specification of the production chemical delivery system or formation of restrictions or
blockages in that system.
— API 17TR13 provides general overview of subsea production systems. It covers descriptions and basic
design guidance on subsea production systems.
4.3.2 Subsea hardware (wellheads, trees, manifolds, structures, connectors, and pumps)
Subsea documents that address assembled equipment include the following.
— API Spec 17D provides specifications for subsea wellheads, mudline wellheads, drill-through mudline
wellheads, vertical and horizontal subsea trees, and the associated tooling for handling, testing, and
installing this equipment.
— API RP 17P provides recommendations for subsea structures and manifolds used for pressure control in
both subsea production of oil and gas and subsea injection ser-vices.
— API RP 17X provides guidance for the design, manufacture, installation, and operation of subsea pumps,
including rotary displacement and rotodynamic types for single-phase and multiphase services. It
applies to all subsea pump modules placed at or above the mudline.
— API 17TR3 documents the results of a study of the risks and benefits of additional penetrations in subsea
wellheads below the blowout preventer (BOP) stack for the purpose of monitoring additional casing
annuli for sustained casing pressure. Special attention was paid to the risk and benefits introduced
by monitoring annuli other than the “A” annulus (the annulus between the production tubing and the
production casing strings).
— API 17TR4 addresses the impact of operation in deepwater on the pressure rating of equipment is a special
concern. The objective of API 17TR4 is to foster a better understanding of the effects of simultaneous internal
and external pressures on the rated working pressure of equipment covered by the scope of API 17D.

ISO 13628-1:2025(en)
— API 17TR7 provides requirements and recommendations for the verification and validation of subsea
connectors along the vertical centreline of subsea hardware (i.e. tree, tubing head, tree cap, tree running
tool, well control package connectors and EDP connectors), the subsea wellhead, and the completion/
workover riser. The methodology provided in API 17TR7 may also be used in other connector designs.
Connectors outboard of the vertical centreline are addressed in API 17R.
— API 17TR8 typically cover deepwater applications where the shut-in pressure is 103,5 MPa (15 000 psi)
or less. In recent years, industry has been pursuing deepwater assets that have shut-in pressures above
103,5 MPa (15 000 psi); and operators and regulatory agencies have had to address these applications
on a singular basis. API 17TR8 establishes a standardized industry approach to the analysis, design,
material selection, testing, and application of subsea component hardware for these high-pressure high-
temperature (HPHT) applications.
— API 17TR11 provides guidance to the industry on allowable pressure loading of subsea hardware
components that can occur during hydrotesting of subsea flowlines and risers and during pre-
commissioning leak testing of these systems. There are potential problems with confusion arising from
high hydrostatic pressure in deepwater, partially due to the variety of applicable test specifications and
partly from the inconsistent use of a variety of acronyms for pressure terminology.
— API 17TR12 provides a detailed review of the full system considerations that are to be taken into account
if one is to consider external pressure in the design of an irregular-shaped subsea pressure-containing
or pressure-controlling device.
4.3.3 Flowlines and risers
Subsea documents that address risers and flowlines include the following.
— API RP 17B, API Spec 17J, API Spec 17K, API Spec 17L1, and API RP 17L2 These documents provide
a comprehensive treatment of the design, manufacture, testing, packaging, and utilization criteria for
both bonded and unbonded flexible pipe, as well as the ancillary equipment necessary to control the
flexible pipe behaviour, protect a transition area, or provide a means of attachment and seal.
— API RP 17R provides applicable criteria for all types of remote connections, and associated pipework,
made between subsea flowline/pipeline end connections, manifolds, and subsea trees. It covers subsea
flowline connectors and jumpers used for pressure containment in both subsea production of oil and gas
and subsea injection services.
— API RP 17U provides guidance for the performance, qualification, application, quality control, handling,
and storage requirements of wet and dry thermal insulation for subsea applications in the petroleum
and gas industries. It also covers the inspection of the insulation and the repair of insulation defects.
— API 17TR1 defines the methodology and test procedures necessary for the evaluation of polymeric
materials suitable for use as the internal pressure sheath of unbonded flexible pipes in high-temperature
applications. It describes the processes by which the critical material properties, both static and dynamic,
can be measured and evaluated against relevant performance criteria.
— API 17TR2 provides comprehensive guidance on materials and pipe issues regarding the use and
operation of PA-11 in flexible pipe applications, typically in production and gas handling applications
up to 100 °C. It concentrates on the use of PA-11 in the internal sheath of flexible pipes, although similar
considerations may also apply to other uses of PA-11 within flexibles, e.g. anti-wear layers, intermediate
sheathes, and outer sheathes.
4.3.4 Control systems
Subsea documents that address control system requirements include the following.
— API Spec 17E specifies requirements for the design, material selection, manufacture, design verification,
testing, installation and operation of subsea umbilicals and their ancillary equipment. It applies to
umbilicals for static or dynamic service, with surface-surface, surface-subsea, and subsea-subsea
routings.
ISO 13628-1:2025(en)
— API Std 17F provides criteria for the design, manufacture, testing, and operation of various types of
surface control system equipment, subsea control systems, and requirements for the associated control
fluids. This equipment is used for control of subsea production of oil and gas and for subsea water and
gas injection services.
— API RP 17S provides minimum requirements for subsea multiphase flow meters to help assure mechanical
and electrical integrity, communications capability, and measurement performance for reliable use.
— API 17TR9 is a reference guide during the early field development planning stage to ensure that due
consideration is given to the implications of the size of UTAs and possible consequences during
installation.
— API 17TR10 address installation of subsea umbilical terminations (SUTs), the risks of installation and
the measures required to minimize these risks.
4.3.5 Intervention systems
Subsea documents that address requirements for intervention systems include the following.
— API Std 17G defines a minimum set of requirements for performance, design, materials, testing and
inspection, hot forming, welding, marking, handling, storing, and shipping of new build subsea well
intervention equipment [through-BOP intervention riser system (TBIRS) and open-water intervention
riser system (OWIRS)].
— API RP 17G3 provides design guidelines for the use of non-ferrous materials in subsea intervention
systems and components.
— API RP 17G5 provides the requirements for the design, manufacture, and testing of intervention workover
control system (IWOCS) equipment.
— API RP 17H provides recommendations for the development and design of remotely operated subsea tools
and interfaces on subsea production systems to maximize the potential of standardizing equipment and
design principles. Criteria for standardized interfaces found in this document are used in nearly all other
subsea operations (e.g. drilling, construction) that require remotely operated vehicle (ROV) support or
interaction.
— API RP 17W captures the best practices in the design and operation of existing capping stacks and
provides a foundation for consistent practices in the design, manufacture, testing, and utilization of
future stacks. It is intended to be applied to the construction of new subsea capping stack components,
but can be also used to improve existing subsea capping stacks.
5 Systems engineering
5.1 General
Consistent with the following definitions provided by the International Council on Systems Engineering
(INCOSE), system engineering of subsea production systems should address the complete system, from the
reservoir to the host facility.
— “A system is an arrangement of parts or elements that together exhibit behaviour or meaning that the
individual constituents do not.”
— “Systems engineering is a transdisciplinary and integrative
...