International Journal of Greenhouse Gas Control最新文献

{"title":"Capturing or offsetting carbon emissions: techno-economic evaluation of decarbonising industries with CO2-lean flue gas","authors":"Sina Hoseinpoori,&nbsp;David Pallarès,&nbsp;Filip Johnsson","doi":"10.1016/j.ijggc.2026.104803","DOIUrl":"10.1016/j.ijggc.2026.104803","url":null,"abstract":"<div><div>This work investigates the technical feasibility and costs of carbon capture from industrial emission sources with CO₂ concentrations of 0.5–4.0%. Three post-combustion capture schemes are considered: monoethanolamine absorption (MEA-ABS); alkali absorption combined with calcium looping (ALK-ABS); and temperature vacuum swing adsorption (TVSA), the latter two commonly investigated for direct air capture. Capture and avoidance costs are compared across industrial sectors, varying the flow rate and CO₂ concentration of the flue gas, and contrasted with the price of offsetting the emissions through purchases of carbon dioxide removal credits at current voluntary-market prices.</div><div>The results show that MEA-ABS has the lowest levelized cost of capture (LCOC) for flue gas streams with larger flow rates (&gt;200 t/h) and CO₂ concentrations ≥1%. TVSA presents the lowest LCOC at lower flow rates (especially &lt;100 t/h), while ALK-ABS has the lowest LCOC only within a small window of low CO₂ concentration (0.5–1%) and 100–200 t/h. Accounting for the carbon footprints of the input energy changes this picture: the carbon avoidance costs (assuming a transport and storage cost of 105 $/tCO₂) reach their lowest values with ALK-ABS, unless heat with a low carbon intensity is available for MEA-ABS. Comparing the cost of carbon avoidance with carbon dioxide removal credits on the voluntary market, it can be more economical for industries with flue gases with CO₂ concentrations &lt;2.6% to offset their emissions through the purchase of such credits than to install any of the post-combustion capture technologies considered here.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104803"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160736","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Deployment potential and economic cost analysis of CCUS in high-emission industries: A case study of Liaoning Province, China","authors":"Huan You,&nbsp;Jinguang Yan,&nbsp;Jingyao Jia,&nbsp;Chengkang Gao,&nbsp;Guoqiang Sang,&nbsp;Jiutian Zhang,&nbsp;Ciang Ding,&nbsp;Ying Zhang","doi":"10.1016/j.ijggc.2026.104800","DOIUrl":"10.1016/j.ijggc.2026.104800","url":null,"abstract":"<div><div>Achieving China’s dual-carbon goals requires accelerated CCUS deployment, yet provinces with concentrated emissions and limited site-level storage remain understudied. This study developed a plant-level source-sink database for Liaoning Province and applied a MILP model enhanced with DBSCAN to assess mitigation potential, costs, and matching strategies. Annual CO₂ emissions from coal power, steel, and cement plants reached 112.43, 141.32, and 22.04 Mt. Storage capacity in oil fields and saline aquifers totaled 25.69 Gt. However, most oil fields cannot independently meet sequestration needs. Within 250 km, 13 cement plants could be matched, achieving 9.09 Mt CO₂ mitigation demand at –42.24 $/t. Clustering oil fields into three groups increased cement-sector mitigation to 10.32 Mt and lowered costs to –87.88 $/t, although this configuration did not support matches for steel plants or coal-fired power plants. This is a planning-oriented screening and matching study conducted under specific assumptions: a 250 km transport distance limit, a project start year of 2030, and a 30-year operational lifetime, rather than a full dynamic deployment pathway analysis. This study offers a theoretical foundation and pathway reference for other industrial provinces under storage-constrained conditions.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104800"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160737","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Assessing readiness for CC(U)S: are we there yet?","authors":"Peta Ashworth,&nbsp;Bishal Bharadwaj,&nbsp;Richard Norman","doi":"10.1016/j.ijggc.2026.104797","DOIUrl":"10.1016/j.ijggc.2026.104797","url":null,"abstract":"<div><div>Given the slow progress on climate mitigation across the world, the need for carbon capture and storage (CCS) to reduce carbon dioxide (CO₂) emissions is being increasingly discussed across society. However, the public remains ignorant of CCS and the role it may play in reducing CO₂ emissions. This means responses to CCS projects can be reactionary rather than based on knowledge of CCS project attributes. To overcome this gap, we used a Discrete Choice Experiment, to investigate: (i) under what conditions do individuals choose a CCS project (or not)? and (ii) what are the attributes that influence preferences for the different forms of CCS? This was seen as a way to address the shortfall of previous public perception research by focusing on the different attributes of CCS projects. We used a market research company to conduct an online survey across seven countries (N=7264) including Australia, the United Kingdom, the United States, Canada, Denmark, Brazil and Indonesia. While there were small differences in preferences across countries, all respondents preferred projects that showed higher benefits - maximising the CO₂ captured for the lowest cost. The other finding was that respondents were less likely to choose projects storing CO₂ locally. These three findings highlight the areas that require most attention for communicating and engaging communities for local CCS projects. While not insurmountable, there is a need to ensure financing CCS projects do not become a burden on the public through subsidies. A more nuanced approach is required to ensure CCS becomes mainstreamed into global mitigation strategies.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104797"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160739","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Designing carbon contract for difference incentives to drive the deployment of carbon capture and storage in Europe","authors":"Toby Lockwood,&nbsp;Adriana Matić,&nbsp;Tobias Johan Sørensen","doi":"10.1016/j.ijggc.2026.104798","DOIUrl":"10.1016/j.ijggc.2026.104798","url":null,"abstract":"<div><div>Carbon contracts for difference (CCfDs) have become a leading policy option in Europe for funding the deployment of carbon capture and storage (CCS) and other industrial decarbonisation projects. This mechanism aims to cover the gap between project costs and the prevailing carbon price over a given project duration. This paper assesses existing CCfD schemes in five European states, highlighting the design choices available to policy makers and their impact on CCS deployment. Design choices include parameters such as project eligibility and selection criteria, payment symmetry, price indexing, and performance criteria. Variation between these schemes is a result of different national contexts and policy visions for CCS development. Countries with weaker political support for CCS or a focus on industrial decarbonisation have tended to prefer CCfD programmes open to multiple decarbonisation technologies. Countries with a strategic vision to deploy CCS technology for multiple purposes have developed technology-targeted schemes. A fundamental challenge for CCS projects is a reliance on shared CO₂ infrastructure, which creates co-dependencies with other projects and can increase cost uncertainty. Design features to address this challenge have included regional prioritisation, cross-chain risk mitigation, consortium bids, and flexibility to changing costs. Project selection and performance criteria can be tailored to promote goals such as near-term abatement, net-zero compatibility, and wider economic impact. As more countries develop CCfDs to meet their decarbonisation goals, this paper offers a structured comparison of the motivating factors and outcomes of key design choices for CCS, so as to inform the design of future schemes.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104798"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160741","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Techno-economic analysis of promoter-enhanced CO2 capture with electrochemical regeneration: A comparative study with CESAR1 on a CHP plant","authors":"Friday O. Ochedi,&nbsp;Sotirios Efstathios Antonoudis,&nbsp;Ilias Kakanis,&nbsp;Grigorios Itskos,&nbsp;Fariborz Shaahmadi,&nbsp;Ashween Kaur Virdee,&nbsp;John Andresen,&nbsp;Susana Garcia,&nbsp;Mijndert van der Spek","doi":"10.1016/j.ijggc.2026.104802","DOIUrl":"10.1016/j.ijggc.2026.104802","url":null,"abstract":"<div><div>This study presents a techno-economic analysis (TEA) comparing an alkaline solvent-based carbon capture technology utilizing electrochemical regeneration (ConsenCUS) with a conventional amine-based thermal regeneration approach (CESAR1) when retrofitted to a combined heat and power (CHP) plant to capture 0.45 Mtonne CO₂ annually. The study also investigates the integration of immobilized carbonic anhydrase (CA) as a promoter to enhance CO₂ absorption kinetics in the ConsenCUS system (ConsenCUS-CA). The results demonstrate that CESAR1 has a regeneration energy requirement of 3.23 GJ_th/tonne CO₂, compared with 3.74 GJ_el/tonne CO₂ for ConsenCUS. Meanwhile, ConsenCUS-CA demonstrates significant improvements, including an 18.6% reduction in solvent requirement, a two-thirds decrease in absorber height, and an 18.4% reduction in electrical regeneration energy requirement, resulting in a 14.1% decrease in total capital requirement, a 12.2% decrease in operating cost, and a 22.3% decrease in the cost of CO₂ avoided when using renewable energy. Despite requiring 30% lower capital investment than CESAR1, ConsenCUS-CA incurs up to 23% higher annual operating costs, primarily due to the electricity required for electrochemical regeneration. The impact of regeneration energy sources is also examined. The economic comparison shows that CESAR1, using a natural gas boiler for steam generation, has an €11.38/tonne CO₂ higher cost of CO₂ avoided but a €2.60/tonne steam lower additional steam production cost than ConsenCUS-CA using renewable electricity. The study further examines the impacts of technological learning, electricity price, CA cost and lifetime, CO₂ emission price, discount rate, plant lifetime, and potential performance improvements on the economic viability of the technologies. The findings indicate that, with continued technological development, ConsenCUS-CA could achieve operating cost parity with CESAR1 if its electrical energy consumption is reduced by at least 25%.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104802"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160743","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The scale of direct air capture in a net-zero California","authors":"Dimitri M. Saad,&nbsp;Katrin Sievert,&nbsp;Mo Sodwatana,&nbsp;Mathis Heyer,&nbsp;Andea Scott,&nbsp;Bjarne Steffen,&nbsp;Adam R. Brandt","doi":"10.1016/j.ijggc.2026.104809","DOIUrl":"10.1016/j.ijggc.2026.104809","url":null,"abstract":"<div><div>California’s 2045 net-zero goal relies heavily on carbon dioxide removal (CDR). Ninety-eight percent of CDR is expected to come from engineered systems such as direct air capture (DAC) and carbon storage. However, uncertainty in future DAC costs obscures its role in California’s decarbonization pathway. We address this gap by using the BRIDGES model, a multi-year sector-coupled gas-electricity capacity expansion model for California, to assess the deployment of two DAC technologies under varying cost assumptions. Specifically, we incorporate technology-specific data for liquid solvent and solid sorbent DAC like capital expenditures, operations and maintenance costs, and energy consumption. We develop scenarios that explore DAC upscaling and deployment. We find that 16 to 33 Mt_CO₂/year of DAC capacity is part of a cost-optimal energy system in 2045 that abates emissions from electric power, buildings, and industry. While DAC deployment does not significantly impede the transition to a variable renewable energy-dominant system, it enables the continued use of natural gas for high-temperature industrial heat and natural gas-powered electricity generation. Even in scenarios with zero natural gas combustion, DAC is utilized to address persistent residual emissions, such as hydrofluorocarbon leaks in building appliances and uncaptured CO₂ in industrial carbon capture and storage systems. These results position DAC as a critical complement to deep decarbonization, highlighting its role in managing residual emissions.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104809"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149200972","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Legacy plugged and buried wells: A limited contribution to Germany's methane emissions","authors":"S. Schloemer,&nbsp;M. Blumenberg,&nbsp;S.F.A. Jordan","doi":"10.1016/j.ijggc.2026.104801","DOIUrl":"10.1016/j.ijggc.2026.104801","url":null,"abstract":"<div><div>Methane (CH₄) emissions from abandoned oil and gas wells are increasingly recognized as potential contributors to anthropogenic greenhouse gas inventories. However, empirical data regarding the long-term integrity of plugged and buried wells in Germany remains sparse. This study aims to quantify CH₄ fluxes from legacy wells in Lower Saxony (Northern Germany) to evaluate their environmental relevance.</div><div>We conducted a field survey of 92 wells. The study design employed a multi-tiered approach, integrating surface flux measurements with soil gas analysis. To distinguish between deep thermogenic leakage and shallow biogenic signals, we analyzed soil gas compositions (hydrocarbons, CO₂) and stable carbon isotope ratios at both, well locations and reference grids.</div><div>Statistical analysis reveals no significant differences in methane concentrations or flux rates between well locations and reference sites. Of the 92 wells examined, 20 showed at least one positive emission at the surface. Only 3 indicate time-varying and low leaking of natural gas (max 40 mg/h/well); two revealed an anomaly (possible shallow biogenic gas) and the remainder are considered natural background levels or are caused by other processes (e.g. peat mining).</div><div>The findings suggest that plugged and buried wells in Germany do not reveal systemic integrity failures and indicates that abandonment practices are effective. Further, microbial methane oxidation in the vadose zone may also serve as an efficient natural filter. While caution is warranted when upscaling these results to the &gt;25,000 legacy wells nationwide, this study implies that these features represent a limited contribution to Germany’s methane emissions.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104801"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160751","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Risk sharing in cooperative game models for CO2 storage with uncertain geology and pressure competition","authors":"Per Pettersson,&nbsp;Svenn Tveit,&nbsp;Sarah E. Gasda","doi":"10.1016/j.ijggc.2026.104807","DOIUrl":"10.1016/j.ijggc.2026.104807","url":null,"abstract":"<div><div>With an increasing number of prospective geological CO₂ storage projects and potential pressure communication between different projects, risk sharing under uncertain geological conditions is relevant to many project operators. In this work, the project operators are modeled as agents in a stochastic cooperative game. The agents can have different risk attitudes, here defined as being willing to accept more or less uncertainty in the predicted storage of CO₂. This uncertainty stems from lack of knowledge of geological parameters as well as unknown future actions of competing agents, and the corresponding probability distributions need to be estimated by numerical simulation.</div><div>The agents can choose to share commercial risk if collaboration is preferable to a baseline scenario of individual injection. If their operations affect each other by means of, e.g., pressure communication, there may be no unique natural definition of a baseline scenario. As a remedy, we suggest belief distributions that combine uncertainty in physical data with maximum entropy prior distributions over the sets of viable injection actions.</div><div>For a realistic storage site, exemplified by the Utsira Formation in the North Sea, we present numerical results for both cases of pressure competition, and no hydraulic connections between different project operations. It is shown that risk averse agents benefit from collaboration when there is no pressure communication or other interference between agents. It is also demonstrated that pressure communication leads to large variability in the feasible injection rates, but the resulting belief distributions are nevertheless informative and useful for decision making about collaboration.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104807"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149200974","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The role of fault characterization in CO2 containment risk assessment – a review","authors":"Elin Skurtveit,&nbsp;Anita Torabi,&nbsp;Yves Guglielmi","doi":"10.1016/j.ijggc.2026.104810","DOIUrl":"10.1016/j.ijggc.2026.104810","url":null,"abstract":"<div><div>Fault zones are key structures controlling subsurface fluid migration and localization of deformations. Although faults have been extensively studied for decades, emerging CO₂ storage projects face challenges quantifying CO₂ fault leakage risk as part of the overall containment risk assessment. This review first outlines the role of faults in CO₂ containment risk with focus on fault zone mapping, architecture and models for fault seal integrity evaluation. Further, we emphasise the hydraulic and mechanical properties in mudrock faults and highlight advances in understanding hydromechanical coupling during fault reactivation based on insight from underground research laboratories. Finally, we discuss the implications for CO₂ containment risk and summarize future research needs for mudrock faults.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104810"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149200975","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Mapping the public evidence base for CO2 storage monitoring and assurance","authors":"Junqing Sun,&nbsp;Mohan Shangguan,&nbsp;Huaxiu Qin,&nbsp;Cong Li,&nbsp;Di Yang,&nbsp;Xiaojun Sun,&nbsp;Yiming Li,&nbsp;Jinren Lu,&nbsp;Haoshuai Li,&nbsp;Yang Li,&nbsp;Mutai Bao","doi":"10.1016/j.ijggc.2026.104804","DOIUrl":"10.1016/j.ijggc.2026.104804","url":null,"abstract":"<div><div>Rapid expansion of carbon capture, utilization, and storage (CCUS) is increasing the need for publicly accessible environmental evidence that can support monitoring design, storage assurance, permitting, and post-closure oversight across diverse storage settings. Public records remain dispersed across controlled-release experiments, operating projects, natural analogues, incident datasets, project databases, and regulatory documents. We assembled a purposively curated corpus of 23 evidence modules and 1110 project records. Of these, 18 modules contained harmonized contribution coding for the canonical matrix, while five served defined non-matrix roles. The 18 × 99 matrix contained 111 documented-positive cells (6.23%); 95 of 99 raw dimensions were represented, but 80 occurred in only one module. The 86 retained dimensions were grouped into 42 parent concepts, of which 13 were supported by one substantive module, 29 by at least two, and 15 by at least three. The single-module count ranged from 11 to 17 across threshold and QICS checks, and external inclusion of Aquistore reduced it to 10. Seven jurisdictions were above the country-screen medians for both deployment pressure and documented deficit intensity, while only Qatar, Saudi Arabia, and the United Arab Emirates remained in that archetype throughout the full evidence-regulatory weight scan. The screen represents monitoring and disclosure workload, not leakage risk. Transferability was constrained by geological setting, duration, wellbore and pathway context, baseline design, analytical QA/QC, and data accessibility. Priority actions are comparable measurements across contrasting settings, longer public time series, and reporting systems that preserve contextual and methodological information for reuse.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"156 ","pages":"Article 104804"},"PeriodicalIF":5.9,"publicationDate":"2026-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"149160738","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}