ISO/TC 265 - Carbon dioxide capture, transportation, and geological storage

This document provides definitions, guidelines and supportive information for the key performance parameters and their characterization methods of absorption liquids used in post-combustion CO2 capture. It covers common methodologies to measure and calculate specific key performance parameters of the absorption liquids. The absorption liquids for post-combustion CO2 capture covered by this document are chemically reactive liquids, such as amine solutions, potassium carbonate solutions, aqueous ammonia, amino-acid salt solutions and mixtures of these reactants. Other absorption liquids based on different principles for CO2 capture are not covered. The key performance parameters considered in this document relate to the design and operation of absorption liquid-based post-combustion CO2 capture processes, as well as equipment such as absorber and desorber columns, reboilers and other heat exchangers. The key performance parameters are: — primary parameters, such as rich and lean CO2 loading, absorbent concentration, absorption capacity, heat of absorption, absorption rate and absorbent volatility; — secondary parameters, such as cyclic loading, that are directly derived from the primary parameters, or combined with other physical measurements, as in the case for the absorbent loss rate. In addition, physical and chemical properties such as density, viscosity, pH, thermal conductivity and specific heat capacity are described. These properties are essential for understanding the key performance parameters of the absorption liquids. This document also: — establishes key performance parameters (see REF Section_sec_4 \r \h Clause 4 08D0C9EA79F9BACE118C8200AA004BA90B02000000080000000E000000530065006300740069006F006E005F007300650063005F0034000000 ), physical and chemical properties of absorption liquids, and their calculation methods, and provides a common way of reporting them; — specifies the general requirements for the absorption liquid characterization in laboratory measurement and field testing (see REF Section_sec_5 \r \h Clause 5); — provides the requirements for the instrumentation to be installed or used, and guidelines for the characterization methods (see REF Section_sec_6 \r \h Clause 6 08D0C9EA79F9BACE118C8200AA004BA90B02000000080000000E000000530065006300740069006F006E005F007300650063005F0036000000 ); — provides information on the characterization methods of absorption liquids, describing all stages of test preparation, set-up and execution (see Annexes A to I), as well as guidance on sampling absorption liquids. NOTE While key performance parameters of absorption liquids are important process indicators for post-combustion CO2 capture, factors such as process design, equipment design and manufacturing, economics and safety are also considered for a comprehensive evaluation of post-combustion CO2 capture technology. The document does not provide guidelines for benchmarking or comparing absorption liquids for post-combustion capture processes, nor does it offer methods to assess different technologies or projects, or specify methodologies for process engineering design. Additionally, the document is not intended to compel technology owners to disclose any intellectual properties related to their proprietary absorption liquids. The document does not cover all available and emerging characterization methods for the key performance parameters considered in this document.

This document examines various CO2 injection operations that involve modifications to CO2-EOR or other complementary hydrocarbon recovery operations that can be conducted in conjunction with CO2 storage. The document also examines potential policy, regulatory or standards development issues that can arise in evaluating such operational changes.

This document provides insights into the essential aspects of CO2 shipping and provides basic descriptions of how the CO2 carrier and technology therein is technically integrated with the CCS value chain. It also includes a description of specific challenges of transporting CO2 as cargo, how this differs from other gases transported by ships today, and how this influences the ship design and operation. Finally, this document introduces how CO2 ships are regulated within the existing international maritime regulatory framework. This document's main focus is on the technical aspects of CO2 shipping. Commercial, liability and financial aspects are intentionally kept out of this document. However, general reference to commercial impact is made where relevant. This document focuses on the ship transportation of CO2 between loading and offloading facilities where the system boundaries are at the ship manifold equipment that connects the ship to the other components in the value chain. In the document, the basis for the description of ship operation is transportation between two shore-based terminals. A high-level description of other relevant interfaces is given on a conceptual level as this has impact on the ship design. However, any further description of potential solutions upstream and downstream from the CO2 carrier is outside the scope. This document also gives a high-level description of the physical properties of CO2 streams at the conditions relevant for shipping and how relevant impurities can impact the ship and ship operation.

This document specifies the requirements and recommendations for the transportation of CO2 streams from the capture site to the storage facility where it is primarily stored in a geological formation or used for other purposes (e.g. for enhanced oil recovery or CO2 use). This document applies to the transportation of CO2 streams by — rigid metallic pipelines, — pipeline systems, — onshore and offshore pipelines for the transportation of CO2 streams, — conversion of existing pipelines for the transportation of CO2 streams, and — transportation of CO2 streams in the gaseous and dense phases. This document also includes aspects of CO2 stream quality assurance, as well as converging CO2 streams from different sources. Health, safety and environment aspects specific to CO2 transport and monitoring are also considered in this document. Transportation of CO2 via ship, rail or on road is not covered in this document.

This document describes and explains the physical and chemical phenomena, and the technical issues associated with flow assurance in the various components of a carbon dioxide capture and storage (CCS) system and provides information on how to achieve and manage flow assurance. The gaps in technical knowledge, limitations of the tools available and preventative and corrective measures that can be taken are also described. This document addresses flow assurance of CO2 streams in a CCS project, from CO2 capture via transport by pipeline and injection well through to geological storage. It does not specifically address upstream issues associated with CO2 sources and capture, although flow assurance will inform CO2 capture design and operation, for example, on constraints on the presence of impurities in CO2 streams, as there are too many different capture technologies to be treated in detail in this document. Vessel transport and buffer storage that are considered in integrated CCS projects under development, are not covered in this document. Flow of material in the supply chain of a CO2 source, even if delivered by a pipeline (e.g. blue hydrogen generation), and flow of gas streams within facilities generating and feeding these into a capture facility can impact flow assurance in CCS projects and networks. These are out of the scope of this document as well. This document also examines the impact of impurities on the phase behaviour and physical properties of the CO2 stream which in turn can ultimately affect the continuous supply of the CO2 stream from the capture plant, through the transportation system and into the geological reservoir via injection wells. Flow of fluids in oil reservoirs for the purpose of enhanced oil recovery is not within the scope of this document.

This document covers: — A description of the existing legal frameworks and associated laws and directives covering current and planned projects. — Specific information about CO2 injection facilities based on existing and planned projects that include storage of CO2 in both saline aquifers and CO2-EOR as relevant. This information includes aspects of materials used, surface infrastructure, well design considerations, concepts around well placement strategies, considerations for downhole monitoring tool deployment, well completions, and well and infrastructure maintenance and remediation practices. — Descriptions of current practices regarding operating projects including monitoring, safety, and reporting activities associated with both surface and downhole components of the projects. — Discussion on operational aspects of storing CO2 in hydrocarbon reservoirs including depleting gas fields and reusing facilities. — A description of monitoring requirements and methods including measurements to establish baselines. — A description of existing and emerging tools, accuracy, and expectations for quantification. — A description of regulatory requirements for operating and decommissioning CO2-EOR with associated storage and CCS projects around the world. — A description of decommissioning activities and timelines associated with end-of-project.

This document provides definitions, guidelines and supporting information for evaluating and reporting (with respect to the basic design items ongoing, and the operational results of a reference plant or unit as feedback) to ensure the (designed) performance of a PCC plant integrated with a host power plant. The PCC plant separates CO2 from the power plant flue gas in preparation for subsequent transportation and geological storage. The physical system being addressed is a single power plant, with an optional auxiliary unit to provide thermal energy required for the PCC plant, and a single PCC plant as described in ISO 27919-1. The formulas and methods to assure and maintain reliable performance, presented in this document, describe issues addressed during the design and construction phases and practices that document reliability and availability during routine operation. These practices would also guide ongoing maintenance programmes. This document does not provide guidelines for benchmark, comparison or assessment studies for PCC plant operations using different capture technologies (i.e. absorbents), nor does it specify appropriate operating conditions such as temperature etc.

This document provides an overview of technologies that are under development to capture carbon dioxide (CO2) that is generated during cement manufacture. This document is intended to inform users about the different technologies, including the characteristics, the maturity and the boundaries of these technologies. This document is applicable to organizations involved in the cement industry and other stakeholders (e.g. policy makers). This document addresses technologies for CO2 capture that have potential applications in the cement industry. This document does not address CO2 transport, CO2 storage or CO2 utilization.

The primary aim of this document is to describe the main compositional characteristics of the CO2 stream downstream of the capture unit, taking into account common purification options. Accordingly, this document will characterize the different types of impurities and present examples of concentrations determined in recent capture pilot projects as well as through literature review. It identifies ranges of concentrations, giving priority to in situ measurements when available. The second aim of this document is to identify potential impacts of impurities on all components of the CCS chain, from surface installations (including transport) to the storage complex. For example, impurities can have a significant effect on the phase behaviour of CO2 streams in relation to their concentration. Chemical effects also include the corrosion of metals. The composition of the CO2 stream can also influence the injectivity and the storage capacity, due to physical effects (such as density or viscosity changes) and geochemical reactions in the reservoir. In case of a leakage, toxic and ecotoxic effects of impurities contained in the leaking CO2 stream could also impact the environment surrounding the storage complex. In order to ensure energy efficiency, proper operation of the whole CCS chain and not to affect its surrounding environment, operators usually limit the concentrations of some impurities, which can, in-turn, influence the design of the capture equipment and purification steps. Such limits are case specific and cannot be described in this report; however, some examples of CO2 stream specifications discussed in the literature are presented in Annex A. The required purity of the CO2 stream delivered from the capture plant will to a large degree depend on the impurity levels that can be accepted and managed by the transport, injection and storage operations. The capture plant operators will therefore most probably need to purify the CO2 stream to comply with the required transport, injection, storage specifications or with legal requirements. Monitoring of the CO2 stream composition plays an important role in the management of the entire CCS process. Methods of measuring the composition of the CO2 stream and in particular the concentrations of impurities are described and other parameters relevant for monitoring at the various steps of the CCS chain are described. The interplay between the set CO2 stream specifications and the efficiency of the entire CCS process is also explained. Finally, the mixing of CO2 streams coming from different sources before transport or storage is addressed, and the main benefits, risks and operational constraints are presented.

1.1 Applicability This document applies to carbon dioxide (CO2) that is injected in enhanced recovery operations for oil and other hydrocarbons (CO2-EOR) for which quantification of CO2 that is safely stored long-term in association with the CO2-EOR project is sought. Recognizing that some CO2-EOR projects use non-anthropogenic CO2 in combination with anthropogenic CO2, the document also shows how allocation ratios could be utilized for optional calculations of the anthropogenic portion of the associated stored CO2 (see Annex B). 1.2 Non-applicability This document does not apply to quantification of CO2 injected into reservoirs where no hydrocarbon production is anticipated or occurring. Storage of CO2 in geologic formations that do not contain hydrocarbons is covered by ISO 27914 even if located above or below hydrocarbon producing reservoirs. If storage of CO2 is conducted in a reservoir from which hydrocarbons were previously produced but will no longer be produced in paying or commercial quantities, or where the intent of CO2 injection is not to enhance hydrocarbon recovery, such storage would also be subject to the requirements of ISO 27914. 1.3 Standard boundary 1.3.1 Inclusions The conceptual boundary of this document for CO2 stored in association with CO2-EOR includes: a) safe, long-term containment of CO2 within the EOR complex; b) CO2 leakage from the EOR complex through leakage pathways; and c) on-site CO2-EOR project loss of CO2 from wells, equipment or other facilities. 1.3.2 Exclusions This document does not include the following: a) lifecycle emissions, including but not limited to CO2 emissions from capture or transportation of CO2, on-site emissions from combustion or power generation, and CO2 emissions resulting from the combustion of produced hydrocarbons; b) storage of CO2 above ground; c) buffer and seasonal storage of CO2 below ground (similar to natural gas storage); d) any technique or product that does not involve injection of CO2 into the subsurface; and e) emissions of any GHGs other than CO2. NOTE Some authorities might require other GHG components of the CO2 stream to be quantified.

This document specifies methods for measuring, evaluating and reporting the performance of post-combustion CO2 capture (PCC) integrated with a power plant, and which separates CO2 from the power plant flue gas in preparation for subsequent transportation and geological storage. In particular, it provides a common methodology to calculate specific key performance indicators for the PCC plant, requiring the definition of the boundaries of a typical system and the measurements needed to determine the KPIs. This document covers thermal power plants burning carbonaceous fuels, such as coal, oil, natural gas and biomass-derived fuels, which are producing CO2 from boilers or gas turbines, and are integrated with CO2 capture. The PCC technologies covered by this document are those based on chemical absorption using reactive liquids, such as aqueous amine solutions, potassium carbonate solutions, and aqueous ammonia. Other PCC concepts based on different principles (e.g. adsorption, membranes, cryogenic) are not covered. The PCC plant can be installed for treatment of the full volume of flue gas from the power plant or a fraction of the total (i.e. a slip stream). Captured CO2 is processed in a compression or liquefaction step as determined by the conditions for transportation and storage. The KPIs considered in this document are the following: a) Specific thermal energy consumption (STEC); b) Specific electrical energy consumption (SEC); c) Specific equivalent electrical energy consumption (SEEC); d) Specific reduction in CO2 emissions (SRCE); e) Specific absorbent consumption (SAC) and specific chemical consumption (SCC). The calculations are based on measurements at the boundaries of the considered system, particularly of energy and utilities consumption. The integrated system includes the definition of interfaces between the PCC plant and the power plant. This document includes the following items: — The system boundary which defines the boundaries of the PCC plant and identifies which streams of energy and mass are crossing these boundaries to help power plant operators identify the key streams that are applicable for their particular case. — Basic PCC plant performance which defines the parameters that describe the basic performance of the PCC plant. — Definition of utilities and consumption calculation which lists the utility measurements required and provides guidance on how to convert utility measurements into the values required for the KPIs. — Guiding principles - Basis for PCC plant performance assessment which describes all guidelines to prepare, set-up and conduct the tests. — Instruments and measurement methods which lists the standards available for the relevant measurements and considerations to take into account when applying measurement methods to PCC plants. — Evaluation of key performance indicators which specifies the set of KPIs to be determined and their calculation methods to provide a common way of reporting them. This document does not provide guidelines for benchmarking, comparing or assessing KPIs of different technologies or different PCC projects. NOTE For the purposes of this document, thermal energy and electric energy are expressed by the unit of "J" (Joule) and "Wh" (Watt hour) respectively unless otherwise noted, with a prefix of International System of Units (SI) if necessary. (1 J = 1 W·s, 1 Wh = 1 W·h = 3 600 J).

ISO/TR 27918:2018 is designed to be an information resource for the potential future development of a standard for overall risk management for CCS projects. The risks associated with any one stage of the CCS process (capture, transportation, or storage) are assumed to be covered by specific standard(s) within ISO/TC 265 and other national and/or international standards. For example, the risks associated with CO2 transport by pipelines are covered in ISO 27913. The scope of this document is intended to address more broadly applicable lifecycle risk management issues for integrated CCS projects. Specifically, the focus of this document is on risks that affect the overarching CCS project or risks that cut across capture, transportation, and storage affecting multiple stages. It needs to be noted that environmental risks, and risks to health and safety should be very low for CCS projects provided the project is carefully designed and executed. Risk identification and management is part of the due diligence process. A list of acronyms is included in Annex A. Clause 5 includes an analysis of how a CCS standard could address aspects of risk analysis that apply to all elements of the CCS chain, such as: - risk identification (identifying the source of risk, event, and target of impact)[1]; - risk evaluation and rating; - risk treatment; - risk management strategy and reporting. Clause 6 comprises an inventory of the overarching and crosscutting risks. These include issues such as: - environmental impact assessment; - risk communication and public engagement; - integration risks between capture, storage, and transportation operators, such as risk of non-conformance of CO2 stream to required specifications; - integration risks associated with shared infrastructure (hubs of sources, common pipelines, hubs of storage sites); - risks resulting from interruption or intermittency of CO2 supply and/or CO2 in-take; - risks associated with policy uncertainty; - incidental risks from activities related to the capture, transportation or storage processes without being specifically covered in the respective standards (e.g. management or disposal of water produced as a by-product of CO2 storage). Clause 7 describes implications and considerations for a potential standard on lifecycle risks for integrated CCS projects. [1]As defined in ISO 31000.

ISO 27917:2017 defines a list of cross-cutting terms commonly used in the field of carbon dioxide capture, transportation and geological sub-surface storage including through storage in association with enhanced oil recovery (EOR) operations. ISO 27917:2017 only deals with CO2 geological sub-surface storage. The terms are classified as follows: - general terms and definitions relating to carbon dioxide; - general terms and definitions relating to carbon dioxide capture, transportation and storage; - general terms and definitions relating to monitoring and measuring performance in carbon dioxide capture, transportation and geological storage; - general terms and definitions relating to risk; - general terms and definitions relating to relationships with stakeholders; A list of the main acronyms used is given in Annex A.

ISO 27914:2017 a) establishes requirements and recommendations for the geological storage of CO2 streams, the purpose of which is to promote commercial, safe, long-term containment of carbon dioxide in a way that minimizes risk to the environment, natural resources, and human health, 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 hydrocarbon production or for storage in association with CO2-EOR, c) includes activities associated with site screening and selection, characterization, design and development, operation of storage sites, and preparation for site closure, d) recognizes that site selection and management are unique for each project and that intrinsic technical risk and uncertainty will be dealt with on a site-specific basis, e) acknowledges that permitting and approval by regulatory authorities will be required throughout the project life cycle, including the closure period, although the permitting process is not included in ISO 27914:2017, f) provides requirements and recommendations for the development of management systems, community and other stakeholder engagement, risk assessment, risk management and risk communication, g) does not apply to, modify, interpret, or supersede any national or international regulations, treaties, protocols or instruments otherwise applicable to the activities addressed in ISO 27914:2017, and h) does not apply to or modify any property rights or interests in the surface or the subsurface (including mineral rights), or any pre-existing commercial contract or arrangement relating to such property. The life cycle of a CO2 geological storage project covers all aspects, periods, and stages of the project, from those that lead to the start of the project (including site screening, selection, 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 period, which includes a closure period. Figure 1 illustrates the limits of ISO 27914:2017.

ISO/TR 27915:2017 presents a review of publicly available literature identifying materially relevant issues and options relating to "good practices" for quantifying and verifying GHG emissions and reductions at the project level. Its scope covers all components of the CCS chain (e.g. capture, transport, storage) and includes a lifecycle assessment approach to estimating project level emissions and emission reductions from project assessment, construction and operations, through to completion and post-closure activities. This document considers the following at the project level: - a variety of Q&V related boundaries applicable to all components of a CCS project; - the composition of the CO2 stream, including its purity, and requirements for measuring and verifying the physical and chemical state of the CO2 stream in CCS projects; - identification and quantification of GHG emissions and reductions across integrated CCS components; - monitoring objectives, methodologies, and sampling strategies, including locations, periods, and frequencies; - GHG data collection and reporting; - verifying GHG expectations with agreed verification criteria; - life cycle assessment (LCA) of CCS projects.

ISO 27913:2016 specifies additional requirements and recommendations not covered in existing pipeline standards for the transportation of CO2 streams from the capture site to the storage facility where it is primarily stored in a geological formation or used for other purposes (e.g. for EOR or CO2 use). ISO 27913:2016 applies to - rigid metallic pipelines, - pipeline systems, - onshore and offshore pipelines for the transportation of CO2 streams, - conversion of existing pipelines for the transportation of CO2 streams, - pipeline transportation of CO2 streams for storage or utilization, and - transportation of CO2 in the gaseous and dense phases. The system boundary (see Figure 1) between capture and transportation is the point at the inlet valve of the pipeline, where the composition, temperature and pressure of the CO2 stream is within a certain specified range by the capture process or processes to meet the requirements for transportation as described in this document. The boundary between transportation and storage is the point where the CO2 stream leaves the transportation pipeline infrastructure and enters the storage infrastructure. ISO 27913:2016 also includes aspects of CO2 stream quality assurance, as well as converging CO2 streams from different sources. Health, safety and environment aspects specific to CO2 transport and monitoring are considered.

ISO/TR 27912:2016 describes the principles and information necessary to clarify the CO2 capture system and provide stakeholders with the guidance and knowledge necessary for the development of a series of standards for CO2 capture. This Technical Report also covers technologies, equipment and processes specific to CO2 capture from the viewpoints of the international standardization for the implementation of CCS. The purpose of this Technical Report is to provide guidance for the development of an ISO document related to CO2 capture as part of a CCS chain. This Technical Report covers CO2 capture systems applicable to CO2 emission sources and their respective boundaries, as well as capture technologies, equipment and processes. In addition, it can be used for the development of International Standards under TC 265. The following issues are to be excluded from this Technical Report: - industrial use of CO2; - compression of CO2 (not described in detail); - terminologies not used in this Technical Report.

This technical revision includes an expansion of scope to include a new clause on quantification and verification and updated definitions as beneficial. To facilitate ISO/TC265’s desire to have this guidance publish as soon as possible, this revision will comprise the addition of a quantification and verification of geological storage of CO2 clause as well as the correction of errors or inconsistencies only. Changes to other clauses in the Standard are not proposed as part of this revision, other than those necessary to incorporate quantification and verification.

1. Scope: This document is a part of a series of standards for carbon dioxide (CO2) capture. It specifies methods for measuring, evaluating and reporting the performance of CO2 capture plant connected to a CO2 intensive plant, and which separate CO2 from the CO2 intensive plant exhaust gas in preparation for subsequent transportation and geological storage. In particular, it provides a common methodology to calculate specific key performance indicators for the CO2 capture plant, requiring the definition of the boundaries of a typical system and the measurements needed to determine the KPIs. 2. Policy of work: The series of standards for carbon dioxide capture will be done based on the following fundamental policies: (1) The standards and requirements being developed in the series will depend on the maturity of the content and its practical use to stakeholders. (2) Standards in the series will build on the previous standards. (3) Standards for CO2 capture lend themselves better to a series of individual standards rather than a single comprehensive standard because of the maturity of the technologies and the process differences in power and different Energy Intensive Industries (EII).

This document provides insights into the essential aspects of CO2 shipping and provides basic descriptions of how the CO2 carrier and technology therein is technically integrated with the CCS value chain. It also includes a description of specific challenges of transporting CO2 as cargo, how this differs from other gases transported by ships today, and how this influences the ship design and operation. Finally, this document introduces how CO2 ships are regulated within the existing international maritime regulatory framework. This document's main focus is on the technical aspects of CO2 shipping. Commercial, liability and financial aspects are intentionally kept out of this document. However, general reference to commercial impact is made where relevant. This document focuses on the ship transportation of CO2 between loading and offloading facilities where the system boundaries are at the ship manifold equipment that connects the ship to the other components in the value chain. In the document, the basis for the description of ship operation is transportation between two shore-based terminals. A high-level description of other relevant interfaces is given on a conceptual level as this has impact on the ship design. However, any further description of potential solutions upstream and downstream from the CO2 carrier is outside the scope. This document also gives a high-level description of the physical properties of CO2 streams at the conditions relevant for shipping and how relevant impurities can impact the ship and ship operation.