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4 Integrated project management
4.1 General
4.2 Storage project
4.2.1 Project phases
4.2.2 Project activities that run across multiple phases
4.2.3 Site screening and feasibility phase
4.2.4 Site characterization phase
4.2.5 Design and development phase
4.2.6 Operations phase
4.2.7 Post-injection phase
4.3 Project management plan
4.3.1 General
4.3.2 Project management plan specifications
4.3.3 Project description
4.4 Information management
4.4.1 Information management plan
4.4.2 Project register
5 Site screening, feasibility investigation and characterization
5.1 General
5.2 Site screening
5.3 Site feasibility investigation
5.4 Site characterization and assessment
5.4.1 General
5.4.2 Geological and hydrogeological characterization
5.4.3 Geophysical characterization and assessment
5.4.4 Geochemical characterization and assessment
5.4.5 Geomechanical characterization and assessment
5.4.6 Well characterization and assessment
5.5 Modelling and assessment
5.5.1 General
5.5.2 Geological static modelling
5.5.3 Dynamic modelling
5.5.4 Area of review
6 Risk management
6.1 General
6.2 Risk evaluation criteria
6.3 Risk management plan
6.4 Risk assessment
6.4.1 General
6.4.2 Risk identification
6.4.3 Risk analysis
6.4.4 Risk evaluation
6.5 Risk treatment
6.6 Review and documentation
6.6.1 Review
6.6.2 Documentation
7 Well infrastructure
7.1 General
7.1.1 Objective
7.1.2 Documentation
7.2 Materials
7.2.1 Conditions for use
7.2.2 Materials selection
7.3 Design and construction
7.3.1 General
7.3.2 Risk mitigation
7.3.3 Wells
7.3.4 Tubulars
7.3.5 Cement and well barrier elements
7.3.6 Post-cementing evaluation and remediation
7.3.7 Completion and stimulation
7.3.8 Corrosion control
7.3.9 Conversion of legacy wells
7.3.10 Wellbore monitoring requirements
7.4 Recompletion and workover of wells
7.4.1 General
7.4.2 Conditions for recompletion and workover of wells
7.4.3 Well integrity
7.5 Abandonment of wells
7.5.1 General
7.5.2 Evaluation of existing abandoned wells
7.5.3 Abandonment
8 CO2 storage site operations
8.1 General
8.2 Design of CO2 storage operations
8.2.1 General
8.2.2 Operating parameters
8.3 Operations management plan
8.3.1 General
8.3.2 Storage site description
8.3.3 Roles and responsibilities
8.3.4 Operations and maintenance procedures
8.3.5 Safety plan
8.4 Operating procedures
8.4.1 General
8.4.2 Initial (start-up)
8.4.3 Continuous operations
8.4.4 Shutdown
8.4.5 Start-up following shutdowns
8.5 Maintenance procedures
8.6 Data acquisition, monitoring and testing
8.6.1 General
8.6.2 CO2 stream metering
8.6.3 Well integrity monitoring
8.6.4 Well testing during operations
8.6.5 Corrosion monitoring
8.7 Well intervention (workovers)
8.8 Information management
9 Monitoring and verification
9.1 Purpose
9.1.1 General
9.1.2 Monitoring activities
9.1.3 Verification activities
9.2 M&V program periods
9.2.1 General
9.2.2 Pre-injection phase monitoring
9.2.3 Injection phase monitoring
9.2.4 Post-injection phase monitoring
9.3 M&V plan objectives
9.4 M&V plan design
9.4.1 M&V plan procedures and practices
9.4.2 M&V plan specifications
9.4.3 M&V program contingency monitoring
10 Quantification and verification
10.1 General
10.2 Quantification principles
10.2.1 General
10.2.2 Quantification of input (minput)
10.2.3 Quantification of operational loss (mloss operations)
10.2.4 Loss from the storage complex (mloss storage complex)
10.2.5 De minimis losses
10.2.6 Avoidance of double counting
10.2.7 Quantification of native CO2
10.3 Measurement of input
10.3.1 General
10.3.2 Defining measurement requirements
10.3.3 Metering locations
10.3.4 CO2 stream composition
10.4 Methodologies for quantification of loss
10.4.1 General
10.4.2 Quantification of operational loss (mloss operations)
10.4.3 Quantification of loss from the storage complex (mloss storage complex)
10.5 Quantification documentation and data retention
10.5.1 Initial documentation
10.5.2 Periodic documentation
10.5.3 Data management
10.6 Verification of the quantification
10.6.1 General
10.6.2 Type of verification
10.6.3 Verification approach
10.6.4 Verification opinion
10.6.5 Quantification verification records
11 Project termination
11.1 General
11.2 Criteria for project termination
11.3 Project termination plan
11.4 Project termination qualification process
11.4.1 General
11.4.2 Qualification process activities
11.4.3 Qualification process documentation
Annex A (informative) General well schematic
Annex B (informative) Illustration of quantification principles
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International Standard ISO 27914 | |
Carbon dioxide capture, transportation and storage — Geological storage Captage, transport et stockage du dioxyde de carbone — Stockage géologique Reference number ISO 27914:2026(en) | Second edition 2026-03
© ISO 2026
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COPYRIGHT PROTECTED DOCUMENT
© ISO 2026
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
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Tel. + 41 22 749 01 11
E-mail copyright@iso.org
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Published in Switzerland
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ContentsPage
4 Integrated project management
4.1 General
4.2 Storage project
4.2.1 Project phases
4.2.2 Project activities that run across multiple phases
4.2.3 Site screening and feasibility phase
4.2.4 Site characterization phase
4.2.5 Design and development phase
4.2.6 Operations phase
4.2.7 Post-injection phase
4.3 Project management plan
4.3.1 General
4.3.2 Project management plan specifications
4.3.3 Project description
4.4 Information management
4.4.1 Information management plan
4.4.2 Project register
5 Site screening, feasibility investigation and characterization
5.1 General
5.2 Site screening
5.3 Site feasibility investigation
5.4 Site characterization and assessment
5.4.1 General
5.4.2 Geological and hydrogeological characterization
5.4.3 Geophysical characterization and assessment
5.4.4 Geochemical characterization and assessment
5.4.5 Geomechanical characterization and assessment
5.4.6 Well characterization and assessment
5.5 Modelling and assessment
5.5.1 General
5.5.2 Geological static modelling
5.5.3 Dynamic modelling
5.5.4 Area of review
6 Risk management
6.1 General
6.2 Risk evaluation criteria
6.3 Risk management plan
6.4 Risk assessment
6.4.1 General
6.4.2 Risk identification
6.4.3 Risk analysis
6.4.4 Risk evaluation
6.5 Risk treatment
6.6 Review and documentation
6.6.1 Review
6.6.2 Documentation
7 Well infrastructure
7.1 General
7.1.1 Objective
7.1.2 Documentation
7.2 Materials
7.2.1 Conditions for use
7.2.2 Materials selection
7.3 Design and construction
7.3.1 General
7.3.2 Risk mitigation
7.3.3 Wells
7.3.4 Tubulars
7.3.5 Cement and well barrier elements
7.3.6 Post-cementing evaluation and remediation
7.3.7 Completion and stimulation
7.3.8 Corrosion control
7.3.9 Conversion of legacy wells
7.3.10 Wellbore monitoring requirements
7.4 Recompletion and workover of wells
7.4.1 General
7.4.2 Conditions for recompletion and workover of wells
7.4.3 Well integrity
7.5 Abandonment of wells
7.5.1 General
7.5.2 Evaluation of existing abandoned wells
7.5.3 Abandonment
8 CO2 storage site operations
8.1 General
8.2 Design of CO2 storage operations
8.2.1 General
8.2.2 Operating parameters
8.3 Operations management plan
8.3.1 General
8.3.2 Storage site description
8.3.3 Roles and responsibilities
8.3.4 Operations and maintenance procedures
8.3.5 Safety plan
8.4 Operating procedures
8.4.1 General
8.4.2 Initial (start-up)
8.4.3 Continuous operations
8.4.4 Shutdown
8.4.5 Start-up following shutdowns
8.5 Maintenance procedures
8.6 Data acquisition, monitoring and testing
8.6.1 General
8.6.2 CO2 stream metering
8.6.3 Well integrity monitoring
8.6.4 Well testing during operations
8.6.5 Corrosion monitoring
8.7 Well intervention (workovers)
8.8 Information management
9 Monitoring and verification
9.1 Purpose
9.1.1 General
9.1.2 Monitoring activities
9.1.3 Verification activities
9.2 M&V program periods
9.2.1 General
9.2.2 Pre-injection phase monitoring
9.2.3 Injection phase monitoring
9.2.4 Post-injection phase monitoring
9.3 M&V plan objectives
9.4 M&V plan design
9.4.1 M&V plan procedures and practices
9.4.2 M&V plan specifications
9.4.3 M&V program contingency monitoring
10 Quantification and verification
10.1 General
10.2 Quantification principles
10.2.1 General
10.2.2 Quantification of input (minput)
10.2.3 Quantification of operational loss (mloss operations)
10.2.4 Loss from the storage complex (mloss storage complex)
10.2.5 De minimis losses
10.2.6 Avoidance of double counting
10.2.7 Quantification of native CO2
10.3 Measurement of input
10.3.1 General
10.3.2 Defining measurement requirements
10.3.3 Metering locations
10.3.4 CO2 stream composition
10.4 Methodologies for quantification of loss
10.4.1 General
10.4.2 Quantification of operational loss (mloss operations)
10.4.3 Quantification of loss from the storage complex (mloss storage complex)
10.5 Quantification documentation and data retention
10.5.1 Initial documentation
10.5.2 Periodic documentation
10.5.3 Data management
10.6 Verification of the quantification
10.6.1 General
10.6.2 Type of verification
10.6.3 Verification approach
10.6.4 Verification opinion
10.6.5 Quantification verification records
11 Project termination
11.1 General
11.2 Criteria for project termination
11.3 Project termination plan
11.4 Project termination qualification process
11.4.1 General
11.4.2 Qualification process activities
11.4.3 Qualification process documentation
Annex A (informative) General well schematic
Annex B (informative) Illustration of quantification principles
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).
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 265, Carbon dioxide capture, transportation, and storage.
This second edition cancels and replaces the first edition (ISO 27914:2017), which has been technically revised.
The main changes are as follows:
—
revision of Clause 3 in alignment with other revisions of this document;
—
deletion of the former Clause 4 regarding management systems, to remove content that is well-covered by other standards;
—
addition of a new Clause 4 regarding integrated project management, to provide guidance on how to navigate this document;
—
addition of Clause 10 regarding quantification and verification.
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.
Introduction
Geological storage of carbon dioxide (CO2) is recognized as a key technology for abatement of CO2 emissions to the atmosphere or ocean and is an essential component in the process of CO2 capture and storage (CCS)[1]. This document aims to address the need for safe and effective long-term storage of CO2 (see Figure 1) and to be able to quantify stored CO2.
The life cycle of a CO2 geological storage project covers all phases and activities of the project, from the start of the project including site screening, feasibility investigation, characterization, assessment, engineering, permitting and construction, through the start of injection and proceeding through subsequent operations until cessation of injection and culminating in the post-injection phase, which concludes with project termination.
This document is supplemented by recommended practice manuals for CO2 storage and numerous standards and technical recommendations developed for the oil and gas industry (see References [1] to [12]).
This document does not address the quantification of greenhouse gases (GHGs) other than CO2 for CO2 storage projects. CCS projects quantifying CO2 according to this document can address quantifying, monitoring, reporting, and validating or verifying other GHG emissions reductions or removals through the application of ISO 14064-2 and other parts of the ISO 14064 series as appropriate. Results from the quantification of CO2 stored according to this document can be used according to ISO 14064-2.
NOTEThe post-injection phase in this document corresponds with the post-closure phase defined in the EU CCS Directive[1] and with the post-injection site closure (PISC) period in the US under the Class VI rule[65]. Termination in this document corresponds with the end of the EU Directive[1] post-closure period.
Figure 1 — Entities involved in the storage project life cycle |
ISO_2__fig_1  |
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1Scope
1.1This document:
a)
establishes requirements for the geological storage of CO2 streams in a way that minimizes risk of CO2 losses;
b)
is applicable for both onshore and offshore geological storage within permeable and porous geological strata including hydrocarbon reservoirs where a CO2 stream is not being injected for the purpose of enhancing hydrocarbon production;
c)
includes activities associated with site screening and feasibility investigation, characterization, design and development, operation of storage projects, and preparation for project termination;
d)
recognizes that the geological characteristics, physical boundaries, management, intrinsic technical risk and uncertainties, of each site are likely to be unique for each project and that intrinsic technical risk and uncertainty will be dealt with on a site-specific basis;
e)
provides requirements for integrated project management, including elements of risk management unique to the geological storage of CO2 streams; and
f)
establishes a methodology for quantifying the net mass of CO2 that geological storage projects store in storage unit(s).
Figure 1 illustrates the limits of this document.
1.2This document does not apply to:
a)
temporary storage in tanks or by other means;
b)
the post-termination phase;
c)
injection of CO2 for enhancing production of hydrocarbons or for storage associated with CO2-EOR;
d)
disposal of other acid gases except as considered part of the CO2 stream;
e)
disposal of waste and other matter added for purpose of disposal; or
f)
underground storage using any form of buried container.
If production of hydrocarbons in commercial quantities occurs from the storage unit(s), the storage project is outside of the scope of this document and ISO 27916 applies to CO2 storage. A CO2-EOR project that has stored CO2 in association with CO2-EOR can transition to operate under this document after all production of hydrocarbons from the storage unit(s) has ceased.
2Normative references
There are no normative references in this document.
3Terms 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
abandonment
process and procedures used to permanently end the operation of a well in a manner that meets project objectives (3.30)
Note 1 to entry: Well abandonment is designed to eliminate the physical hazard of the well (the hole in the ground), eliminate a pathway for leakage and prevent changes in the hydrogeological system, such as the changes in hydraulic head and the mixing of formation fluids between hydraulically distinct strata.
3.2
area of review
geographical area(s) designated for assessment of the extent to which a storage project (3.47) can affect life and human health, the environment, competitive development of other resources, or infrastructure
Note 1 to entry: The delineation of an area of review defines the outer perimeters on the land surface or seabed and water surface within which assessments will be conducted as can be required by regulatory authorities.
3.3
baseline
reference basis for comparison against which variance of a measured parameter is monitored or measured
3.4
CO2 plume
carbon dioxide plume
region within geological strata where injected CO2 is present in free phase
3.5
CO2 stream
carbon dioxide stream
stream consisting overwhelmingly of CO2
Note 1 to entry: The stream is a fluid mixture that may include any incidental associated substances (impurities) derived from the source materials or the capture process and any substances added to the stream to enable or improve the injection process or trace substances added to assist in CO2 migration detection.
3.6
confining unit
geological strata that are part of a storage complex (3.45) and effectively restrict migration of fluids out of the storage unit (3.50) and leakage (3.16) out of the storage complex
Note 1 to entry: Described in reservoir engineering as caprock and in hydrogeology as aquitard or aquiclude.
3.7
compartment
portion of a storage unit (3.50) that is geologically and hydraulicly separated from other portions of the storage unit
3.8
containment
retention of CO2 within a storage complex (3.45)
3.9
custody transfer meter
measurement instrument that furnishes quantity and quality information used for quantification and the basis for a change in responsibility for the CO2 stream
3.10
decommission
process of taking an engineered system or component out of service, render it inoperative, dismantle and decontaminate it
3.11
detection threshold
smallest value of a property of a substance or effect that can be reliably detected by a specific method of measurement in a specified context
3.13
3.14
geological storage
Note 1 to entry: Long-term means the minimum period necessary for CO2 geological storage to be considered an effective and environmentally safe climate change mitigation option.
Note 2 to entry: The term “sequestration” has been used by a number of countries and organizations instead of “storage” (e.g. the international “Carbon Sequestration Leadership Forum”). While the two terms are considered to be synonymous, only “storage” is used in this document.
3.15
injectivity
sustainable rate at which fluids can be pumped into the storage unit(s) (3.50) given pressure constraints
3.16
leakage
unintended release of CO2 out of a pre-defined containment (3.8)
[SOURCE: ISO 27917:2017, 3.2.14, modified — "CO2" has been removed from the term and Note 1 to entry has been deleted.]
3.18
likelihood
chance of something happening, expressed qualitatively or quantitatively
3.19
3.20
3.21
mechanical integrity
mechanical condition of a well, such that its ability to function properly and safely is maintained
3.22
mechanical integrity test
MIT
test performed on a well to confirm that it maintains mechanical integrity (3.21)
Note 1 to entry: MITs are a means of measuring the adequacy of the construction of a well and a way to detect problems within the well system.
3.23
monitoring
continuous or periodic checking, supervising, observing, measuring or determining the status of a system to identify change from baseline (3.3)
3.24
native CO2
native carbon dioxide
3.25
operations phase
time and activities from CO2 stream first entering the wellhead for storage until injection ceases
3.26
overburden
geological material between the top of the storage complex (3.45) and the ground surface or seabed
3.27
3.28
post-injection phase
time and activities between the cessation of injection and the demonstration of conformity with the criteria for project termination (3.33)
3.29
post-termination phase
time and activities that begin after the demonstration of conformity with the criteria for project termination (3.33)
3.30
project objective
specific goal the project operator (3.31) pursues towards ensuring the safe, long-term containment (3.8) of stored CO2
Note 1 to entry: Objectives can have different aspects (such as financial, health, safety and environmental goals, research, technology development, public engagement and job creation) and can apply at different levels (such as strategic, organization-wide, project, product and process).
3.31
project operator
entity that is legally responsible for the CO2 storage project (3.47)
3.32
project personnel
person or persons employed by the project operator (3.31), or anyone acting under the project operator’s control or on behalf of the project operator
3.33
3.34
protected groundwater
water found beneath the water table in fully saturated soils and geologic formations that is used for human consumption, agricultural or industrial uses, or is protected from contamination by legislation or regulation
3.35
regulatory authority
entity or entities that have the authority to permit, approve or otherwise authorize one or more storage project (3.47) activities, or monitor conformity with the terms of a permit
3.36
risk
effect of uncertainty on project objectives (3.30)
Note 1 to entry: Level of risk is commonly expressed in terms of both the severity of consequences (negative impacts) of an event and the associated likelihood (3.18) of their occurrence.
Note 2 to entry: An effect is a deviation from the expected and can be either positive or negative.
3.37
risk assessment
process of identifying, analysing and evaluating risk scenarios (3.40)
3.38
risk control
measure that maintains or modifies risk (3.36)
[SOURCE: ISO 31000:2018, 3.8, modified — "risk" has been added to the term, "and/or" has been changed to "or" in the definition and Notes 1 and 2 to entry have been deleted.]
3.39
risk evaluation criteria
terms of reference used to define the magnitude of risk (3.36)
3.40
risk scenario
combination of circumstances that can cause negative impacts on elements of concern (3.12)
3.42
site characterization
3.43
site screening and feasibility investigation
evaluation of the suitability of candidate storage sites (3.49) by identifying, assessing and possibly comparing candidate storage formations or sites
3.44
stakeholder
individual, group of individuals or organization whose interests are or can be affected by a storage project (3.47)
[SOURCE: ISO 27917:2017 3.5.1, modified — "CCS project" has been replaced with "storage project in the definition.]
3.45
3.46
3.47
storage project
sequence of activities associated with the development of a storage facility (3.46), such as site feasibility investigation and characterization as well as design, construction, operation and termination
3.48
3.49
3.50
storage unit
geological stratum (or strata) into which CO2 is injected and contained for the purpose of geological storage (3.14)
3.51
surface facility
equipment used or proposed to be used for geological storage, including wellheads, monitoring (3.23) equipment, distribution lines and other equipment used to connect injection wells, and equipment used to accept or process carbon dioxide streams (3.5) received at a storage facility (3.46), but not pipelines used to transport carbon dioxide to a storage facility
3.52
validation
confirmation that the system under consideration meets, in all respects, the specification of that system
3.53
verification
confirmation by examination and provision of objective evidence that specified criteria are met
3.54
verifier
person or entity with responsibility for performing and reporting on the verification (3.53) process
[SOURCE: ISO 14064-2:2019, 3.3.4, modified — "competent and impartial person" has been replaced with "person or entity" and "on a verification" has been replaced with "on the verification process" in the definition.]
3.55
well barrier
engineered feature or element installed or constructed in the well to prevent unintended release of fluid or gas
3.56
well operation
activity during the lifecycle of a well, including drilling, cementing, operation, maintenance and abandonment (3.1)
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Bibliography
[1] | DIRECTIVE 2009/31/EC OF THE EUROPEAN PARLIAMENT AND OF THE COUNCIL of 23 April 2009 on the geological storage of carbon dioxide and amending Council Directive 85/337/EEC, European Parliament and Council Directives 2000/60/EC, 2001/80/EC, 2004/35/EC, 2006/12/EC, 2008/1/EC and Regulation. (EC) No 1013/2006 | |
[2] | Implementation of Directive 2009/31/EC on the Geological Storage of Carbon Dioxide. Guidance Document 1. CO2 Storage Life Cycle Risk Management Framework, 2024 | |
[3] | Implementation of Directive 2009/31/EC on the Geological Storage of Carbon Dioxide. Guidance Document 2. Characterization of the Storage Complex, CO2 Stream Composition, Monitoring and Corrective Measures, 2024 | |
[4] | Implementation of Directive 2009/31/EC on the Geological Storage of Carbon Dioxide. Guidance Document 3. Criteria for Transfer of Responsibility to the Competent Authority, 2024 | |
[5] | Implementation of Directive 2009/31/EC on the Geological Storage of Carbon Dioxide. Guidance Document 4. Article 19 Financial Security and Article 20 Financial Mechanism, 2024 | |
[6] | The Commonwealth of Australia - Regulations under the Offshore Petroleum and Greenhouse Gas Storage Act 2006. - Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Regulations 2011 - Select Legislative Instrument 2011 No. 54 | |
[7] | BRGM/RP-60369-FR. Lignes de conduite pour la sécurité d’un site de stockage géologique de CO2, 2011 (in French) | |
[8] | CANADIAN STANDARDS ASSOCIATION. Z741-12 Geological Storage of Carbon Dioxide. CSA, Mississauga, 2012 (Reaffirmed 2022) | |
[9] | USEPA. Vulnerability Evaluation Framework for Geologic Sequestration of Carbon Dioxide, in Technical Support Document. 2008, US EPA. | |
[10] | USEPA. Underground Injection Control (UIC) Program Class VI Well Project Plan Development Guidance, US EPA. Office of Water, 2012, | |
[11] | DNV. RP-J203 Geologic Storage of Carbon Dioxide, DNV, Editor. 2012 (Amended 2021-09), Det Norske Veritas AS. | |
[12] | ISO 27916:2019, Carbon dioxide capture, transportation and geological storage — Carbon dioxide storage using enhanced oil recovery (CO2-EOR) | |
[13] | ISO 14064-2:2019, Greenhouse gases — Part 2: Specification with guidance at the project level for quantification, monitoring and reporting of greenhouse gas emission reductions or removal enhancements | |
[14] | ISO 27917:2017, Carbon dioxide capture, transportation and geological storage — Vocabulary — Cross cutting terms | |
[15] | ISO 31000:2018, Risk management — Guidelines | |
[16] | ISO 17348:2016, Petroleum and natural gas industries — Materials selection for high content CO2 for casing, tubing and downhole equipment | |
[17] | API (American Petroleum Institute), API RP 6J, Testing of Oilfield Elastomers, 2nd Edition, 2022 | |
[18] | API (American Petroleum Institute), API TR 5C3, Calculating Performance Properties of Pipe Used as Casing or Tubing, 7th Edition, 2018 | |
[19] | SAE International/ASTM International, Metals and Alloys in the Unified Numbering System {UNS}, 11th Edition {2008}, 2008 | |
[20] | API (American Petroleum Institute), RP 15TL4-1999, Care and Use of Fiberglass Tubulars, 1999 | |
[21] | API (American Petroleum Institute), API Specification 5L, 46th Edition, Line Pipe, 2018 | |
[22] | API (American Petroleum Institute), API Spec 15LR, Low Pressure Fiberglass Line Pipe, 2001 (Reaffirmed 2018) | |
[23] | API (American Petroleum Institute), API Specification 6A, 21st Edition, Wellhead and Tree Equipment, 2019 | |
[24] | API (American Petroleum Institute), Spec 6D-2008, Specification for Pipeline Valves, 2008 | |
[25] | ISO 14313, Oil and gas industries including lower carbon energy — Pipeline transportation systems — Pipeline valves | |
[26] | API (American Petroleum Institute), Bull 6J-1992, Testing of Oilfield Elastomers (A Tutorial), 1992 | |
[27] | API (American Petroleum Institute), Spec 11D1 4th Edition, Packers and Bridge Plugs, 2022 | |
[28] | ISO 14310, Petroleum and natural gas industries — Downhole equipment — Packers and bridge plugs | |
[29] | CSA Group, CSA-Z662:23, Oil and gas pipeline systems, 2023 | |
[30] | API (American Petroleum Institute), SPEC 5CT, Casing and Tubing, 2023 | |
[31] | API (American Petroleum Institute), SPEC 5CRA, Corrosion Resistant Alloy Seamless Tubes for Use as Casing, Tubing, Coupling Stock, 2022 | |
[32] | ISO 15156 (all parts), Petroleum and natural gas industries — Materials for use in H2S-containing environments in oil and gas production | |
[33] | ANSI (American National Standards Institute)/NACE International, ANSI/NACE MR0175-2009, Petroleum and natural gas industries — Materials for use in H2S-containing environments in oil and gas production — Parts 1, 2, and 3, 2009 | |
[34] | NACE International, TM0177-2016, Laboratory Testing of Metals for Resistance to Sulfide Stress Cracking and Stress Corrosion Cracking in H2S Environments, 2016 | |
[35] | API (American Petroleum Institute), API RP 7G, Recommended Practice for Drill Stem Design and Operation Limits, 1998 (Reaffirmed 2015) | |
[36] | API (American Petroleum Institute), API RP 96, Deepwater Well Design and Construction, 1st Edition, 2013 | |
[37] | API (American Petroleum Institute), API RP 74, Occupational Safety for Onshore Oil and Gas Production Operation,2001 (Reaffirmed 2013) | |
[38] | API (American Petroleum Institute), APIRP 75, Safety and Environmental Management System for Offshore Operations and Assets, 2019 | |
[39] | NORSOK-D 010, Revision 4 Well Integrity in Drilling and Well Operations, 2021 | |
[40] | API (American Petroleum Institute), API STD 65-2, Isolating Potential Flow Zones During Well Construction, 2010 (Reaffirmed 2016) | |
[41] | API (American Petroleum Institute), API RP 5A3, Thread Compounds for Casing, Tubing, Line Pipe, and Drill Stem Elements, 2023 | |
[42] | ISO 13678, Petroleum and natural gas industries — Evaluation and testing of thread compounds for use with casing, tubing, line pipe and drill stem elements | |
[43] | API (American Petroleum Institute), API RP 10B-2, Recommended Practice for Testing Well Cements, 2024 | |
[44] | ISO 10426-2:2003, Petroleum and natural gas industries — Cements and materials for well cementing — Part 2: Testing of well cements | |
[45] | API (American Petroleum Institute), API RP 10B-4, Preparation and Testing of Foamed Cement Slurries at Atmospheric Pressure, 2015 (Reaffirmed 2019) | |
[46] | ISO 10426-4:2004, Petroleum and natural gas industries — Cements and materials for well cementing — Part 4: Preparation and testing of foamed cement slurries at atmospheric pressure | |
[47] | API (American Petroleum Institute), API RP 10B-5, Recommended Practice on Determination of Shrinkage and Expansion of Well Cement Formulations at Atmospheric Pressure, 2005 (Reaffirmed 2020) | |
[48] | ISO 10426-5:2024, Oil and gas industries including lower carbon energy — Cements and materials for well cementing — Part 5: Determination of shrinkage and expansion of well cement formulations | |
[49] | API (American Petroleum Institute), RP 10D-2, Centralizer Placement and Stop-collar Testing, 2023 | |
[50] | ISO 10427-2:2004, Petroleum and natural gas industries — Equipment for well cementing — Part 2: Centralizer placement and stop-collar testing | |
[51] | API (American Petroleum Institute), API SPEC 10F, Cementing Float Equipment Testing, 2020 | |
[52] | ISO 10427-3:2003, Petroleum and natural gas industries — Equipment for well cementing — Part 3: Performance testing of cementing float equipment | |
[53] | API (American Petroleum Institute), Spec 10A, Cements and Materials for Well Cementing, 2019 | |
[54] | ISO 10426-1:2009, Petroleum and natural gas industries — Cements and materials for well cementing — Part 1: Specification | |
[55] | API (American Petroleum Institute), Spec 10D, Bow-Spring Casing Centralizers, 2021 | |
[56] | ISO 10427-1:2024, Oil and gas industries including lower carbon energy — Equipment for well cementing — Part 1: Casing bow-spring centralizers | |
[57] | API (American Petroleum Institute), API RP 65, Cementing Shallow Water Flow Zones in Deep Water Wells, 2002 (Reaffirmed 2012) | |
[58] | API (American Petroleum Institute), API TR 10TR1, Cement Sheath Evaluation, 2008 | |
[59] | API Technical Report, Summary of Carbon Dioxide Enhanced Oil Recovery (CO2 EOR) Injection Well Technology | |
[60] | ISO 16530-1:2017, Petroleum and natural gas industries — Well integrity — Part 1: Life cycle governance | |
[61] | API (American Petroleum Institute), API RP 65-3, Wellbore Plugging and Abandonment, 2021 | |
[62] | U.S. Department of Energy and National Energy Technology Laboratory, DOE/NETL-2017/1848, Best Practices: Operations for Geologic Storage Projects, 2017 | |
[63] | API (American Petroleum Institute), Carbon Dioxide (CO2) Emergency Response Tactical Guidance Document, Best Practice Guidelines for Preparedness and Initial Response to a Pipeline Release of Carbon Dioxide (CO2), 2023 | |
[64] | ISO/TR 27915, Carbon dioxide capture, transportation and geological storage — Quantification and verification | |
[65] | USEPA Class VI regulations, 40 CFR Part 146 Subpart H | |
[66] | IOGP Report 676 – Well abandonment and integrity evaluation for CO2 storage | |
[67] | IOGP Report 670 – Risk and Uncertainty Assessments for Geologic Storage of CO2 |
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ICS 13.020.40 Price based on 56 pages
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