Carbon Capture And Storage Projects Research Articles

The Ones and Zeros of Carbon Capture

Leading services companies and specialty software firms alike have launched various tools and digital suites to assist carbon capture and storage (CCS) project operators with everything from ideal siting of facilities and pipelines to the efficient operations and around-the-clock monitoring of those facilities. CCS holds the promise of big business if industry can efficiently and economically operate at scale the slate of planned facilities. Oil and gas companies have been making investments in the space with aims to become leaders in a segment—ironic since the petroleum business is also one of the emitters of CO2 into the atmosphere. Last month, supermajor ExxonMobil executed the largest offshore CO2 storage lease in the US with the Texas General Land Office. The 271,000-plus-acre site complements the onshore CO2 storage portfolio ExxonMobil is developing and further solidifies the US Gulf Coast as a CCS leader, according to the operator. In an October 2024 report, the US Department of Energy (DOE) issued a draft strategy for carbon management technologies through 2030, stating that carbon capture and direct air capture are “essential” to achieving net-zero greenhouse gas emissions by 2050. The report says CCS projects will grow dramatically over the next decade and beyond, adding that 18 CCS facilities are operating now in the US. DOE’s near-term CCS strategy through 2030 incorporates focusing research, development, demonstration, and deployment funding on priority use cases; building out CO2 transportation and storage infrastructure where it likely will be needed most in the future; supporting the implementation of effective and evidence-driven policies and regulations related to carbon management at other federal agencies; engaging communities and workers to ensure projects deliver benefits and mitigate potential risks to public health and the environment; and supporting climate diplomacy efforts to accelerate the adoption of carbon management at scale globally in a way that aligns with the Paris Agreement. “DOE is funding a variety of technologies to assist in decarbonization in the industrial and power sectors,” the report explained. “These approaches include carbon management as well as electrification, fuel switching, materials substitution, efficiency, and other emissions-reductions measures. In parallel, DOE is working to envision and develop transformative emissions reductions approaches that will create new options in the long term.” The US government has been an active participant in making funding available for the advancement of CCS technologies. In 2024 alone, almost $3.5 billion was made available between two separate programs—CCS large-scale pilot projects ($937 million) and CCS demonstration projects ($2.5 billion)—as part of the Bipartisan Infrastructure Law. In June 2023, ceremonial shovels were plunged into the dirt in Ector County, Texas, to mark the start of construction for the largest direct air capture facility in the world, designed to capture 500,000 metric tons of CO2 from the atmosphere every year. Occidental subsidiary OnePointFive’s $1-billion Stratos project is located on a 65-acre site made up of a network of air contactors, pellet reactors, a centrifuge, and a calciner—all known components that operate in other industries.

The Why, What, Who, When, and Where of Carbon Capture and Storage in Southern Ontario

This paper reviews the five Ws (Why, What, Who, When, and Where) of carbon capture and storage in southwestern Ontario. This area is home to nearly one quarter of Canada’s population and approximately three-quarters of one million people work in the manufacturing sector. Fifteen of the province’s top 20 CO2 emission point sources are in this area. The industries responsible for these emissions include steel mills, refineries and petrochemical plants, and cement plants. These industries are part of the hard-to-abate sector, in that CO2 is used or generated as an integral part of the industrial process. As such, eliminating or even reducing emissions from these industries is a difficult task. Carbon capture and storage (CCS) projects aim to sequester that gas in sedimentary basins over periods exceeding several thousand years. To this end, deeply buried (> 800 m) porous and permeable rocks (a repository) must be overlain by impermeable rocks that act as a seal, preventing the upward migration of CO2 into the atmosphere. The possibility that injection activities could trigger seismicity is but one of the additional considerations. When operational, CCS projects have a negative carbon footprint and the desirability of developing and using this technology has been established for over 20 years. True CCS projects differ from carbon capture, utilization, and storage (CCUS) projects in that the former are only designed with sequestration in mind. One type of CCUS project involves using CO2 for enhanced oil recovery (EOR) and this technology has been employed for several decades. Cambrian sandstones are the most suitable injection targets for CCS in southwestern Ontario because previous oil and gas drilling has shown the rocks to have the necessary characteristics. They are buried below 800 m, can be tens of metres thick, and have adequate porosity and permeability. However, the Cambrian section is lithologically and stratigraphically heterogeneous and oil, gas, and brine can all be present in the pore space. The extent to which this complexity will affect CO2 injection has not yet been evaluated.

Nanoscale Understanding on CO2 Diffusion and Adsorption in Clay Matrix Nanopores: Implications for Carbon Geosequestration.

Carbon capture and storage (CCS) in subsurface reservoirs represents a highly promising and viable strategy for mitigating global carbon emissions. In the context of CCS implementation, it is particularly crucial to understand the complex molecular diffusive and adsorptive behaviors of anthropogenic carbon dioxide (CO2) in the subsurface at the nanoscale. Yet, conventional molecular models typically represent only single-slit pores and overlook the complexity of interconnected nanopores. In this work, finite kaolinite lamellar assemblages with abundant nanopores (r < 2 nm) were used. Molecular dynamics simulations were performed to quantify the spatial distribution correlations, adsorption preference, diffusivity, and residence time of the CO2 molecules in kaolinite nanopores. The movement of the CO2 molecules primarily occurs in the central and proximity regions of the siloxane surfaces, progressing from larger to smaller nanopores. CO2 prefers smaller nanopores over larger ones. The diffusion coefficients increase, while residence times decrease, with the pore size increasing, differing from typical slit-pore models due to the pore shape and interconnectivity. The perspectives in this study, which would be challenging in conventional slit-pore models, will facilitate our comprehension of the CO2 molecular behaviors in the complex subsurface clay sediments for developing quantitative estimation techniques throughout the CCS project durations.

Estimating Carbon Dioxide Solubility in Brine Using Mixed Effects Random Forest Based on Genetic Algorithm: Implications for Carbon Dioxide Sequestration in Saline Aquifers

Summary Accurate prediction of carbon dioxide (CO2) solubility in brine is crucial for the success of carbon capture and storage (CCS) by means of geological formations like aquifers. This study investigates the effectiveness of a novel genetic algorithm-mixed effects random forest (GA-MERF) model for estimating CO2 solubility in brine. The model’s performance is compared with established methods like the group method of data handling (GMDH), backpropagation neural networks (BPNN), and traditional thermodynamic models. The GA-MERF model utilizes experimental data collected from literature, encompassing key factors influencing CO2 solubility: temperature (T), pressure (P), and salinity. These data are used to train and validate the model’s ability to predict CO2 solubility values. The results demonstrate the superiority of GA-MERF compared to the other models. Notably, GA-MERF achieves a high coefficient of determination (R) of 0.9994 in unseen data, indicating a strong correlation between estimated and actual CO2 solubility values. Furthermore, the model exhibits exceptionally low error metrics, with a root mean squared error (RMSE) of 2×10-8 and a mean absolute error (MAE) of 1.8×10-11, signifying outstanding accuracy in estimating CO2 solubility in brine. Beyond its high accuracy, GA-MERF offers an additional benefit—reduced computational time compared to the other models investigated, with 65 seconds. This efficiency makes GA-MERF a particularly attractive tool for real-world applications where rapid and reliable CO2 solubility predictions are critical. In conclusion, this study presents GA-MERF as a powerful and efficient model for predicting CO2 solubility in brine. Its superior performance compared to existing methods and previous literature highlights its potential as a valuable tool for researchers and engineers working on CCS projects utilizing aquifer storage. The high accuracy, low error rates, and reduced computational time make GA-MERF a promising candidate for advancing the development of effective and efficient CCS technologies.

Assessing carbon capture and storage technology in industrial joint venture

Carbon Capture and Storage (CCS) technology can effectively reduce carbon dioxide emissions from industrial and energy production processes. Yet the commercialization of CCS technology is hampered by financial requirements. Existing research compares the costs and benefits of business models for individual CCS projects, no studies assess the industry and national levels. Here we use a dynamic computable general equilibrium model, constructure the vertical integration and joint venture business models for CCS. This study assesses the emission and economic impacts of joint ventures between China's high-emission industries and their upstream and downstream sectors. We find that adopting the joint venture model in the coal power sector, compared to the vertical integration model, initially exerts a negative economic impact but can mitigate 0.04 % of GDP by 2060. The chemical industry consistently benefits from the joint venture model both economically and in emission reductions. Downstream sectors of the steel and cement industries are unsuitable for participation in joint ventures. In addition, the joint venture model has significant industry linkage effects, affecting energy consumption, the scale and cost of CCS deployment. This work provides important information for the large-scale commercialization of CCS technology.

CO2 trapping dynamics in tight sandstone: Insights into trapping mechanisms in Mae Moh's reservoir

The reliance on fossil fuels is a major contributor to increased anthropogenic CO2 emissions, driving global challenges such as climate change through the greenhouse effect. Carbon capture and storage (CCS) is a promising interdisciplinary technology aimed at mitigating these emissions by securely sequestering gigatons of CO2. This study focuses on the feasibility of storing point-source CO2 emissions in saline formations, with a particular emphasis on the Mae Moh coal-fired power plant in Lampang, Thailand, which is located near its associated coal mine. The region presents challenges due to tight sandstone reservoirs buried over 2000 m deep. With reservoir simulation, this study evaluates the impact of various factors on CO2 containment and trapping in these geological settings. Results show that elevated temperatures decrease structural trapping of 43.0%–28.9% and increase solubility trapping of 28.55%–46.5%, at 40 °C and 80 °C respectively. Hysteresis is found to enhance residual trapping by immobilizing up to 31.1% of CO2 within pore spaces at 0.5. Permeability heterogeneity has a minimal impact on overall trapping efficiency due to the less heterogeneity of the tight sandstone. However, the kV/kH ratio significantly influences vertical CO2 migration which resulted in residual trapping at its highest at the ratio of 0.1, while lower ratios support lateral dispersion. Moderate rock compressibility values are identified as optimal for structural and residual trapping, while extreme compressibility enhances solubility trapping by up to 30%. These findings emphasize the complexity of CO2 trapping mechanisms in tight sandstone formations, emphasizing the need for careful consideration of key factors in CCS projects.

Investigating the Impacts of Carbon Pricing Mechanism on CCS development in ASEAN countries

Abstract Carbon Capture and Storage (CCS) is a technology that contributes toward a reduction in carbon dioxide (CO2) emissions from large point sources. It has been proven to be a crucial technology to decarbonise ASEAN’s hard-to-abate industry sector. ASEAN countries are a concentrated cluster, contributing to significant emissions, and provides the potential for suitable geological storage for CCS according to current studies. This paper discusses the impact of carbon pricing on the CCS development in ASEAN countries, through studying factors that enable or disable successful CCS projects. Causal Loop Diagram (CLD), as a part of system dynamics, was employed as an analytical tool to identify and visualize the key variables, system’s structure, the network of existing carbon pricing mechanisms and other financing instruments needed in CCS deployment. The results of this study indicate that strong public and private finance, the development of carbon markets, and carbon pricing policies are the key enablers for CCS projects in ASEAN. Carbon pricing should be viewed as an effective catalyst that helps the growth of CCS with the right policies in place, government and regulatory support, and market forces.

Environmental impacts and scale-up efficiency of four carbon capture and storage scenarios

Capture, transportation, and permanent storage of CO2 is considered pivotal in reaching global net-zero emission targets. Conceptualization and deployment of carbon capture and storage (CCS) value chains require substantial resources with current CCS projects trailing behind expectations. To date few studies address the environmental impacts related to introducing CCS into existing value chains, and even fewer focus on the environmental efficiency of scaling-up CCS projects, despite the need for acceleration. Four scenarios were studied, resembling CCS projects at different capture capacities of 0.3, 1.5, 3.5 and 10 million tonnes of CO2 per year (mtpa) deployed within a Northern European region. Using attributional life cycle assessment, we demonstrate that permanent carbon storage today may furnish a 47–91% CO2 net-abatement potential depending on the CO2 source and geographical location of CCS projects. Despite limited operational data, results appear robust with general low uncertainty. Our environmental assessment show that capturing, conditioning and liquefaction account for the largest emission shares of the studied CCS value chains, ranging from 70 to 80%, which is heavily fluctuated by the carbon emission intensity of regional electricity production. Impacts related to permanent storage activities, such as offshore monitoring and well drilling are limited to less than 2% across all scenarios. Moreover, our study suggests that expanding the spatial geographical scope to accumulated 5000 km has a low influence on the efficiency of CCS value chains regardless of capture rate. Freshwater eutrophication shows the highest burden across the assessed environmental impact categories caused by the electricity production for capture processes. Lastly, we identify net-abatement improvement potential for post-combustion CCS projects at capturing capacities between 1.5 and 10 million tonnes per annum ranging from 10 to 20% for transport-related activities, and 60–68% for capturing processes when assuming net-zero energy scenarios.

Experimental and thermodynamic modelling of hydrate dissociation conditions for CO[formula omitted] + propane mixtures

The possibility of hydrate formation poses a central issue for Carbon Capture and Storage (CCS) and Enhanced Oil Recovery with Water-Alternating-Gas (EOR/WAG) injection projects. In most of the cases, however, the available fluid for this purpose consists of a CO2-rich stream containing contaminants such as hydrocarbons and permanent gases. As a result, there is a growing interest in evaluating the effect of small impurities concentrations on the phase behaviour of such streams. This work investigates the impact of propane as a promoter in carbon dioxide hydrate formation, covering a concentration range in the feed gas phase between 10 and 69% on mole basis. The study also considers the Lw-LCO2-H region, taking into account liquid and supercritical transportation commonly encountered in CCS projects. Additionally, a procedure to estimate uncertainties in the graphical determination of the dissociation temperature and pressure is discussed. The thermodynamic modelling approach includes three different modifications of cubic equations of state (CEoS): asymmetric mixing rule, advanced Huron-Vidal mixing rule, and cubic-plus-association approach. An alternative procedure based on setting different sets of CO2 Kihara’s parameters when shifting between structures was also used. While satisfactory average temperature deviations were obtained for those equations of state, maximum deviation between calculated and experimental temperatures spanned from 0.5 to 2.5 K, depending on the thermodynamic model.

Impact assessment of the residual lifespan of coal-fired power plants on the investment risk of carbon capture and storage retrofit

This research constructs an assessment model for carbon capture and storage (CCS) retrofit of coal-fired power plants (CFPP) by adopting the real option theory. Due to the prohibitive costs associated with retrofitting and insufficient residual lifespan of CFPP, CCS projects may fail to recoup their investment before units are decommissioned. The key contribution of this paper is that it investigates the impact of the residual lifespan of the units on the failure rate of the retrofit investment in addition to the optimal timing of the unit's CCS retrofit. Considering different installed capacities, utilization hours, clean energy subsidy and carbon trading mechanism, this study sets up seven scenarios to assess the impact of different investment environments on the value of project investment. In terms of sensitivity analysis, the residual lifespan of the unit, its interaction with carbon price, carbon price volatility, technological advancement rate, and subsidy level are examined for their impacts on the project investment risk. The findings suggest that the critical period for determining the long-term success of most coal-fired unit retrofits may be present, and more supportive policies need to be examined to facilitate the green transformation and upgrading of coal-fired units.

Offset VSP acquired with a single-use fiber-optic probe: Gorgon CCS case study

There are many challenges associated with monitoring industrial subsurface CO2 storage. Utilizing a reliable strategy for monitoring and assurance is paramount. Numerous aspects and trade-offs need to be considered when designing a cost-effective monitoring solution that must satisfy regulatory and social licensing requirements and minimize operational complexity. Among various geophysical techniques that are included in the suite of carbon capture and storage (CCS) monitoring programs, seismic surveys provide reliable observations of the deep subsurface. However, active surface seismic techniques are expensive, resulting in significant time separation between surveys (several months or years). Downhole seismic approaches combined with fiber-optic sensing provide flexible options in designing on-demand monitoring strategies. Distributed acoustic sensing offers the opportunity to utilize injection wells for downhole time-lapse seismic imaging and microseismic detection, minimizing the impact on production operations. This paper presents the results of a multioffset vertical seismic profiling survey acquired in CO2 injection wells using bare fibers. The fibers were deployed inside the production tubing through FiberLine Intervention technology developed by Well-SENSE. The test utilized two injection wells for active seismic acquisition. The study took place on Barrow Island (Western Australia) as part of the Gorgon CCS project. The study demonstrates the technological advantages of fast deployment of the sensing fiber and the high quality of acquired seismic data. The paper highlights characteristic noise patterns in the recorded data and suggests approaches to attenuate their effects on seismic image quality. Finally, the impact of survey geometry and directional sensitivity of fiber on the recorded wavefield and the quality of seismic imaging is discussed.

Absolute permeability estimation from microtomography rock images through deep learning super-resolution and adversarial fine tuning

The carbon capture and storage (CCS) process has become one of the main technologies used for mitigating greenhouse gas emissions. The success of CCS projects relies on accurate subsurface reservoir petrophysical characterization, enabling efficient storage and captured CO2\\documentclass[12pt]{minimal} \\usepackage{amsmath} \\usepackage{wasysym} \\usepackage{amsfonts} \\usepackage{amssymb} \\usepackage{amsbsy} \\usepackage{mathrsfs} \\usepackage{upgreek} \\setlength{\\oddsidemargin}{-69pt} \\begin{document}$$\ extrm{CO}_2$$\\end{document} containment. In digital rock physics, X-ray microtomography (μ\\documentclass[12pt]{minimal} \\usepackage{amsmath} \\usepackage{wasysym} \\usepackage{amsfonts} \\usepackage{amssymb} \\usepackage{amsbsy} \\usepackage{mathrsfs} \\usepackage{upgreek} \\setlength{\\oddsidemargin}{-69pt} \\begin{document}$$\\upmu $$\\end{document}-CT) is applied to characterize reservoir rocks, allowing a more assertive analysis of physical properties such as porosity and permeability, enabling better simulations of porous media flow. Estimating petrophysical properties through numeric simulations usually requires high-resolution images, which are expensive and time-inefficient to obtain with μ\\documentclass[12pt]{minimal} \\usepackage{amsmath} \\usepackage{wasysym} \\usepackage{amsfonts} \\usepackage{amssymb} \\usepackage{amsbsy} \\usepackage{mathrsfs} \\usepackage{upgreek} \\setlength{\\oddsidemargin}{-69pt} \\begin{document}$$\\upmu $$\\end{document}-CT. To address this, we propose using two deep learning models: a super-resolution model to enhance the quality of low-resolution images and a surrogate model that acts as a substitute for numerical simulations to estimate the petrophysical property of interest. A correction process inspired by generative adversarial network (GAN) adversarial training is applied. In this approach, the super-resolution model acts as a generator, creating high-resolution images, and the surrogate network acts as a discriminator. By adjusting the generator, images that correct the errors in the surrogate’s estimations are produced. The proposed method was applied to the DeePore dataset. The results shows the proposed approach improved permeability estimation overall.

THE ROLE OF GOVERNMENT SUPPORT IN THE DEVELOPMENT OF THE CCS MARKET: EXPERIENCE OF COUNTRIES WITH A DEVELOPED OIL AND GAS INDUSTRY

The article examines the role of government support in the development of the Carbon Capture and Storage (CCS) Technology market in countries with a developed oil and gas industry. It is shown that the implementation of CCS in the oil and gas sector has significant economic and environmental importance, as it allows not only to reduce the large-scale greenhouse gas emissions of this industry but also to increase the oil recovery factor through the injection of captured CO2 into depleted reservoirs. An analysis of the cost chain of various stages of the CO2 capture, transportation, and storage process is carried out, and the most costly elements are identified. The economic aspects of using Carbon Capture, Use, and Storage (CCUS) Technology for enhanced oil recovery are considered, and the need for government subsidies to ensure the commercial attractiveness of such projects under low CO2 emission prices is justified. The global experience of using economic instruments (carbon taxation, tax incentives, grants) to stimulate CCS projects in various industrial sectors is investigated. Significant differences in the approaches of leading countries compared to Russia are revealed. Pilot initiatives of the largest Russian oil and gas companies for the implementation of CCS technologies are analyzed. Recommendations are formulated for the creation of favorable regulatory conditions and effective mechanisms of government stimulation for the widespread adoption of CCS in Russia, taking into account its specifics as a major hydrocarbon producer.

Factors Shaping Public Support for More Carbon Capture and Storage Projects in the United States.

This study contributes to the literature examining public acceptance of carbon capture and storage (CCS) projects in the US. The examination of factors that shape public support for CCS projects provides policymakers with insights to address public concerns, balance CCS development with public sentiments, and make informed decisions about optimal locations and timing. Based on a nationally representative survey on 1850 respondents, the study finds that in the US, there is very low familiarity (6.4%) regarding CCS technology and some limited opposition (11.5%) to increased CCS development. Regression results suggest that support for increased CCS projects in the US is influenced by perceptions of technical and social risks (leakage and community danger, respectively) but not cost of living risks, perceptions of environmental and economic benefits, familiarity with the technology, confidence in government regulations, and a desire for the US to lead in CCS. We fail to find the 'Not-in-My-Backyard' effect, and individuals supporting the development of more CCS in their states also support it at a national level. Understanding these factors helps policymakers anticipate challenges in implementing CCS initiatives and allows for the development of strategies to address concerns.

Future directions in geological research impacting renewable energy and carbon capture: A synthesis of sustainable management techniques

Geological research plays a pivotal role in shaping the future of renewable energy and carbon capture initiatives, offering insights into sustainable management techniques. This review synthesizes the future directions in geological research that impact renewable energy and carbon capture, focusing on sustainable management techniques. Future geological research will increasingly focus on enhancing the integration of renewable energy sources into existing energy systems. This includes the development of innovative geological mapping techniques to identify and characterize renewable energy resources with greater precision, aiding in the selection of optimal sites for energy production. Additionally, there will be a growing emphasis on utilizing geological data to assess the feasibility of carbon capture and storage (CCS) projects, particularly in volcanic regions, where the unique geological characteristics offer potential for efficient carbon sequestration. Another key aspect of future geological research is the advancement of monitoring and modeling techniques to evaluate the long-term performance and environmental impact of renewable energy and CCS projects. This includes the use of advanced geophysical and geochemical methods to monitor subsurface changes associated with energy extraction and carbon storage, ensuring the effectiveness and safety of these practices. Furthermore, future research will explore the potential of geological formations, such as deep saline aquifers and depleted oil and gas reservoirs, for large-scale carbon storage. This will involve developing strategies to enhance storage capacity and mitigate the risk of CO2 leakage, contributing to the sustainable management of carbon emissions. In conclusion, future geological research will play a critical role in advancing renewable energy and carbon capture technologies, offering sustainable management techniques that are essential for addressing climate change. By focusing on innovative mapping, monitoring, and modeling approaches, researchers can pave the way for a more sustainable energy future.

Criteria and workflow for selecting saline formations for carbon storage

Carbon capture and storage (CCS) is an essential greenhouse gas mitigation strategy. Consolidating CO2 sources and sinks can enable the widespread adoption of CCS, and the success of hub-scale projects depends on finding an appropriate sequestration complex. This work developed a criteria-driven framework to assess the potential suitability of saline formations for carbon storage. The workflow uses a three-stage process that screens, ranks, and characterizes potential saline storage formations based on three categories: (1) capacity and injectivity optimization, (2) retention and geomechanical risk minimization, and (3) siting and economic constraints. In this framework, data confidence has been incorporated into site ranking, which provides the user with information about the degree of uncertainty associated with the evaluation. The methodology can be applied to sites in various geological and geographical environments and incorporates general and project-specific criteria. This quantitative, criteria-driven approach was applied to two areas of interest in the Gulf of Mexico, and one site was identified for further assessment. In addition, this workflow was applied to four existing CCS projects— Sleipner, IBDP, In Salah, and Snøhvit—to see how they would have scored and ranked pre-development.

Technology readiness level assessment of carbon capture and storage technologies

The global energy sector has experienced significant expansion in recent years, driven by rising demand and technological advancements. This growth has led to both opportunities and challenges, including global warming and the need to offset global carbon emissions. A wide range of technological maturity characterizes the current state of carbon capture and storage (CCS) technologies. To efficiently navigate and accelerate the implementation of these solutions, conducting an in-depth assessment of various CCS technologies is necessary. In the literature, maturity assessment-based study of CCS technologies exists only using expert surveys. This study aimed to conduct a technology readiness level (TRL) assessment of CCS technologies with the help of a multi-faceted approach comprising a literature review, technology identification, data collection, TRL mapping, expert survey, and comparative analysis. To achieve this, 79 CCS projects from the literature were analyzed to identify growing trends in the CCS industry. The analysis shows that both pre-combustion and post-combustion capture are mature technologies achieving TRL 9, while oxy-fuel capture is ranked at TRL 7. Similarly, carbon storage technologies achieved high ranking, enhanced oil recovery (EOR) and storage in saline aquifers are fully commercial and ranked at TRL 9. Enhanced coal bed methane (ECBM) extraction is trailing at TRL 3 in the research phase. In addition, a total of 21 experts were surveyed, and their statements corroborate the conclusions of the literature review. The research concludes that post-combustion capture and EOR are the most popular CCS technologies, respectively.

Securing the Australian CCS project rollout by improving aspects of the GHG storage legislation: a discussion paper

The respective Federal petroleum and greenhouse-gas (GHG) storage legislation was examined in detail to understand the interactions between the technical requirements in the legislation, the overarching emissions-policy framework and the existing and likely future technical capabilities of the carbon capture and storage (CCS) industry. Key elements of the GHG legislation were then stress-tested using CCS project examples to determine applicability. The number of CCS projects required to meet the nation’s emission reduction targets over the next 5–25 years is high (probably between 20–40 projects of 4 million tonnes per annum (Mtpa)), but the existing 8–10 year approvals timeline provides only a maximum of 2.5 full project cycles to undertake 20–40 projects, a goal not considered possible without substantial regulatory reform. Opportunities for improvement should focus on facilitating a robust and rapid CCS project rollout and could include the following: changing the legislation to facilitate the accelerated utilisation of depleted petroleum fields to storage facilities, including allowing the progressive expansion of the awarded injection licence (IL); changing the concept of containment to emphasise carbon dioxide (CO2) plume management via assessing risk and potential impacts, not by artificial constraints into GHG permits and licences; including unitisation and combination pathways in the GHG legislation; ‘CO2 plume’ is not defined in legislation, even though the spatial location of a plume is central to numerous approvals, such as declaration of storage, demonstrating containment and all measurement, monitoring and verification (MMV) programs; developing a framework to manage future CCS project interactions at a basin scale, as is undertaken in groundwater management onshore.

Challenges and opportunities in Australian greenhouse gas storage legislation: insights from the CarbonNet project

Co-funded by the Victorian and Australian Governments, the CarbonNet Project (CarbonNet) was established in 2009 to enable commercial deployment of carbon capture and storage (CCS). The duration and first-of-a-kind nature of the project has also provided an opportunity to test the Australian legislative greenhouse gas (GHG) framework. Although the Commonwealth legislative regime has comprehensive GHG legislation in place, one of the recognised barriers to geological storage in Australia is permitting and regulatory complexity. CarbonNet’s practical application of the legislation has emphasised that regulatory maturity will only be achieved once a number of projects have been permitted through the full project lifecycle. While the project has achieved many regulatory firsts, there have been several policy and regulatory challenges. Successes have come via legislative reform, scientific investigation and collaboration, and stakeholder engagement and communication. This paper provides insights into CarbonNet’s regulatory journey and key learnings in testing first-of-a-kind regulatory processes. It also explores opportunities for improvement in the GHG regulatory framework, while noting the progress of recent legislative reform and government collaboration. The paper concludes with a recognition of the need for the CCS regulatory framework to be straightforward, fit-for-purpose, proportionate, risk-based, and not overly prescriptive or complex. CCS projects may span decades and require significant upfront investment from multiple companies or consortia. Proponents and investors require confidence in the regulatory framework underpinning a project before making these large commitments. Accordingly, there is a key role for both Australian and State governments in providing the enabling legislative and regulatory framework for CCS projects.

Defining the geomechanical operating limits for subsurface CO2 storage

Carbon capture and storage (CCS) is a critical component of proposed pathways to limit global warming, though considerable upscaling is required to meet emissions reduction targets. Quantifying and managing the risks of fault reactivation is a leading barrier to scaling global CCS projects from current levels of ~40 million tonnes of carbon dioxide(CO2) per year (to target levels of several gigatonnes of CO2 per year), because CO2 injection into reservoirs can result in increased pore-fluid pressure and temperature changes, which can reduce the strength of rocks and faults and induce brittle failure. This can result in induced seismicity, whilst hydraulic fracturing of seals could provide pathways for CO2 leakage. Consequently, identifying favourable geomechanical conditions (typically determined through data on pre-injection rock stress, mechanical and elastic properties, and pore-fluid pressures) to minimise deformation of reservoirs and seals represents a key challenge in the selection of safe and effective sites for CCS projects. Critically, however, such geomechanical data are typically spatially limited (i.e. restricted to wells) and mainly consist of pre-injection crustal stress orientation measurements, rather than a full 3D description of the stress tensor and related geomechanical properties. This paper reviews some key geomechanical issues and knowledge gaps (particularly those associated with data availability and limitations) that need to be understood to enable successful reservoir and seal management for CCS projects. We also highlight recent advances in multi-scale and dimensional geomechanical modelling approaches that can be used to assess sites for the secure storage of CO2 as well as other gases, including hydrogen.