International Journal of Greenhouse Gas Control最新文献

{"title":"Evaluating offshore legacy wells for geologic carbon storage: A case study from the Galveston and Brazos areas in the Gulf of Mexico","authors":"Greg Lackey ,&nbsp;Scott Pantaleone ,&nbsp;John K. Montgomery ,&nbsp;Kristen Busse ,&nbsp;Adam W. Aylor ,&nbsp;Tracy J. Moffett","doi":"10.1016/j.ijggc.2024.104276","DOIUrl":"10.1016/j.ijggc.2024.104276","url":null,"abstract":"<div><div>Federal offshore waters in the Gulf of Mexico are of interest for large-scale geologic carbon storage (GCS). However, more than 80,000 offshore oil and gas wells exist in the region, which could impact the integrity of sealing intervals. In this study, we propose a screening methodology for ranking offshore legacy wells based on the challenge they may present to GCS. The methodology relies on the review of well regulatory records to 1) identify leakage pathways and assess the potential hazards that wells pose to planned GCS operations, 2) evaluate well features that impact the accessibility of wells to determine the feasibility of potential corrective actions, and 3) rank wells based on the overall challenge they may pose for GCS. We demonstrate our framework by evaluating the construction and abandonment of 156 wells across eight areas of interest (AOIs) in shallow federal waters along the Texas Gulf Coast. The majority (99.3 %) of wells considered were constructed and plugged in a manner that did not isolate prospective GCS targets in the Upper and Lower Miocene formations and may potentially require a challenging or uncertain corrective action prior to GCS. Dataset trends suggest that the observed well construction and plugging designs may be common in shallow offshore federal waters along the Texas Gulf Coast. Consequently, operators pursuing offshore GCS projects in the region may consider selecting areas that avoid challenging wells or performing robust evaluations of legacy well leakage risks to plan corrective action prior to CO₂ injection.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"139 ","pages":"Article 104276"},"PeriodicalIF":4.6,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142531712","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":"CO2 retention in high-pressure/high-temperature reservoirs of the Yinggehai Basin, northwestern South China Sea","authors":"Jinyan Lin ,&nbsp;Rui Liu ,&nbsp;Niklas Heinemann ,&nbsp;Johannes M. Miocic ,&nbsp;Jinqiang Tian ,&nbsp;Zengyu Chen ,&nbsp;Lin Hu ,&nbsp;Yazhen Zhang ,&nbsp;Julien Amalberti ,&nbsp;Lichao Wang","doi":"10.1016/j.ijggc.2024.104237","DOIUrl":"10.1016/j.ijggc.2024.104237","url":null,"abstract":"<div><div>Global industry drillings targeted at deep-burial hydrocarbons have renewed the record of maximum sustainable overpressure in sedimentary basins. However, the influence of extremely high overpressure on natural fluid accumulation and artificial waste sequestration is not yet completely understood. To better understand the motion characteristics of the highly overpressured CO₂-rich fluid, the CO₂ retention capacity was quantified, and the CO₂-rich fluid motion trails were evaluated in an ideal natural laboratory in the Yinggehai Basin. The hydraulic sealing capacity was higher than the capillary sealing capacity in the highly overpressured stratum. Relative to the situations of no breach or solely breached by capillary failure, the superposition of capillary and hydraulic failures resulted in the caprock integrity breakage by faults (or fractures), diapirs, and pipes. Meanwhile, the high expulsion flux of CO₂-rich fluid caused the consumption of chlorite to generate illite in the caprock of dual-breached fields. The CO₂-rich fluid flux of capillary invasion was limited by the inherently low permeability of caprock, which may be insufficient for a dramatic change of hydrogen ions or electron activities to induce remarkable chlorite dissolution in the caprock of the sole-breached field.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104237"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142529132","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":"An integrated dynamic modeling workflow for acid gas and CO2 geologic storage screening in saline aquifers with faults: A case study in Western Canada","authors":"Alireza Qazvini Firouz ,&nbsp;Benyamin Yadali Jamaloei ,&nbsp;Alejandro Duvan Lopez Rojas","doi":"10.1016/j.ijggc.2024.104258","DOIUrl":"10.1016/j.ijggc.2024.104258","url":null,"abstract":"<div><div>This study investigates the feasibility of storing the acid gas produced from the oil and gas facilities in Southern Saskatchewan into the Basal Sand aquifer using a coupled wellbore-aquifer-compositional reservoir model. The simulations investigate the pressure change around the fault in proximity of the primary storage location incorporating the influence of reservoir permeability, fault transmissibility, and wellbore configuration, on the factors critical to safe and efficient storage, such as plume migration, pressure changes, and CO₂ storage capacity. A compositional fluid model created using an equation of state was integrated into the reservoir model. Simultaneous incorporation of fault transmissibility, phase solubility, water salinity, temporal in-situ hysteresis and structural trapping, and in-situ compositional tracking of individual gas components is considered as the main novelty of this work. The main challenge of the study was the lack of available data to characterize the aquifer. To this end, a comprehensive workflow of reservoir studies and modeling was applied to reduce the uncertainties and evaluate the site selection. The Basal sand scoping models reveal that the aquifer is expected to handle the required disposal volume given its extent. The injected acid gas plume migrates laterally and preferentially towards the northwest, away from the fault, owing to the aquifer's geological structure. CO₂ remains entirely in the supercritical state, offering storage advantages due to its lower volume. The reservoir permeability significantly impacts the pressure patterns with lower permeability formations triggering higher wellhead injection pressures. Substantial pressure increases around the sealing fault can be observed. Pressure changes of 110 kPa (16 psi) to over 400 kPa (58 psi) were observed at the fault segment after 20 years of continuous gas injection for the expected range of reservoir properties. Mitigation strategies to minimize the increase in fault pressure entail relocating the injection site away from the fault or utilizing a horizontal well trajectory and using an observation well near the fault for monitoring any pressure buildup and slippage.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104258"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142423988","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":"Corrigendum to “Cross-sectoral assessment of CO2 capture from U.S. industrial flue gases for fuels and chemicals manufacture” [International Journal of Greenhouse Gas Control 135 (2024) 1-20 / 104137]","authors":"M. Jibran S․ Zuberi,&nbsp;Arman Shehabi,&nbsp;Prakash Rao","doi":"10.1016/j.ijggc.2024.104264","DOIUrl":"10.1016/j.ijggc.2024.104264","url":null,"abstract":"","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104264"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142529133","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":"Development of carbon capture and storage (CCS) hubs in Kazakhstan","authors":"Nurgabyl Khoyashov ,&nbsp;Gaini Serik ,&nbsp;Amina Togay ,&nbsp;Yerdaulet Abuov ,&nbsp;Alisher Alibekov ,&nbsp;Woojin Lee","doi":"10.1016/j.ijggc.2024.104259","DOIUrl":"10.1016/j.ijggc.2024.104259","url":null,"abstract":"<div><div>The competitiveness of both the power and industry sectors in Kazakhstan is due to the use of cheap fossil fuels. Due to the projected large-scale deployment of renewable energy sources in the future, some portions of cheap coal and hydrocarbon use are planned to be phased out in Kazakhstan. In its net-zero journey, the country still intends to have GHG emissions from reduced use of fossil fuels and “hard-to-electrify” industries such as chemicals, cement, and iron/steel sectors. Carbon capture and storage (CCS) is a decarbonization solution to existing fossil fuel-fired power plants and other hard-to-abate industries in the net-zero age, which Kazakhstan officially plans to reach by 2060. This study covers three major research tasks on large-scale CCS deployment in Kazakhstan. The study first reveals the “low-hanging fruits” of CO₂ capture in the natural gas processing and ammonia production industries, with a low cost of capture of $29 per ton of CO₂ captured each, by comparing the costs of capture in Kazakhstan with those of power plants, steel factories, cement plants, refineries, and hydrogen plants. Secondly, this work shows that developing CCS projects in hubs of multiple emitters can bring cost-efficient deployment of CCS in Kazakhstan. Lastly, we presented our vision of how CCS could be a part of Kazakhstan's big net-zero plan in 2060. Our estimates show that 8 CCS hubs in Kazakhstan with a total capacity of 115 Mt CO₂/year could cost $87 billion in capital expenditures (CAPEX) until 2060. While CO₂ capture remains the most expensive component of CCS process chains globally, compressing and transporting CO₂ poses significant cost challenges in Kazakhstan due to the long distances between emission sources and storage sites. Future research endeavors could explore automated tools to optimize logistical considerations and enhance the accuracy of cost estimations. Moreover, further studies should incorporate site-specific data to reduce assumptions and refine CCS potential assessments in Kazakhstan.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104259"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142357643","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":"Simulation analysis of salt precipitation in large-scale CO2 storage using periodic injection via a horizontal well","authors":"Maryam Khosravi,&nbsp;Erling H. Stenby,&nbsp;Wei Yan","doi":"10.1016/j.ijggc.2024.104263","DOIUrl":"10.1016/j.ijggc.2024.104263","url":null,"abstract":"<div><div>This simulation study investigates the novel aspects of salt precipitation and formation damage near a horizontal injector during CO₂ storage in an offshore depleted oil reservoir with high water saturation and non-negligible residual oil. Built upon prior experimental findings, our study delves into the intricate interplay between displacement, evaporation, and capillary backflow during periodic CO₂ injection, necessitating fine gridding (e.g., down to 2 cm) near the wellbore and an equivalent representation of the wellbore area to capture salt precipitation dynamics accurately. A key contribution of this work is the identification and detailed quantitative characterization of three distinct drying regimes—evaporative, capillary, and viscous—based on gas flux at the perforation, which poses unique challenges in reservoir simulation. Notably, our study is the first to demonstrate these drying regimes specifically along a single CO₂ injector well, providing critical insights for reservoir management. The results highlight the significant impact of the capillary regime on injectivity loss and underscore the necessity of refined wellbore grid resolution to mitigate potential total plugging risks. Furthermore, this work evaluates the effects of injection temperature and trapped oil, revealing their suppressive effects on salt precipitation. Importantly, employing a 3D sector model, we explore extreme scenarios such as complete perforation plugging within the capillary regime, showcasing redirection of gas flux to preserve injectivity. Overall, this study advances the field by offering detailed quantitative assessments of drying regimes and underscores the critical importance of tailored simulation approaches for effective reservoir management in complex offshore environments with residual oil.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104263"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142529135","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":"Optimization of pressure management strategies for geological CO2 storage using surrogate model-based reinforcement learning","authors":"Jungang Chen ,&nbsp;Eduardo Gildin ,&nbsp;Georgy Kompantsev","doi":"10.1016/j.ijggc.2024.104262","DOIUrl":"10.1016/j.ijggc.2024.104262","url":null,"abstract":"<div><div>Injecting greenhouse gas (e.g. CO2) into deep underground reservoirs for permanent storage can inadvertently lead to fault reactivation, caprock fracturing and greenhouse gas leakage when the injection-induced stress exceeds the critical threshold. It is essential to monitor the evolution of pressure and the movement of the CO2 plume closely during the injection to allow for timely remediation actions or rapid adjustments to the storage design. Extraction of pre-existing fluids at various stages of the injection process, referred as pressure management, can mitigate associated risks and lessen environmental impact. However, identifying optimal pressure management strategies typically requires thousands of simulations, making the process computationally prohibitive. This paper introduces a novel surrogate model-based reinforcement learning method for devising optimal pressure management strategies for geological CO2 sequestration efficiently. Our approach comprises of two steps. The first step involves developing a surrogate model using the embed to control method, which employs an encoder-transition-decoder structure to learn dynamics in a latent or reduced space. The second step, leveraging this proxy model, utilizes reinforcement learning to find an optimal strategy that maximizes economic benefits while satisfying various control constraints. The reinforcement learning agent receives the latent state representation and immediate reward tailored for CO2 sequestration and choose real-time controls which are subject to predefined engineering constraints in order to maximize the long-term cumulative rewards. To demonstrate its effectiveness, this framework is applied to a compositional simulation model where CO2 is injected into saline aquifer. The results reveal that our surrogate model-based reinforcement learning approach significantly optimizes CO2 sequestration strategies, leading to notable economic gains compared to baseline scenarios.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104262"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142424080","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-environmental study of CO2 and aqueous formate solution injection for geologic carbon storage and enhanced oil recovery","authors":"Abouzar Mirzaei-Paiaman ,&nbsp;Omar A. Carrasco-Jaim ,&nbsp;Ryosuke Okuno","doi":"10.1016/j.ijggc.2024.104257","DOIUrl":"10.1016/j.ijggc.2024.104257","url":null,"abstract":"<div><div>As carbon capture, utilization, and storage (CCUS), carbon-dioxide enhanced oil recovery (CO₂ EOR) has inherent shortcomings, such as inefficient oil recovery and carbon storage, and low storage security with mobile CO₂. This paper presents a techno-economic-environmental analysis of using formate species, a product of CO₂ electrochemical reduction, as an alternative carbon carrier for sequestration and EOR in a carbonate oil reservoir in the Gulf of Mexico Basin. CO₂ injection, water-alternating-CO₂ injection, and aqueous formate solution injection were compared using a compositional reservoir simulation model and an economic calculator. Formate solution injection yielded greater levels of oil recovery and net carbon storage, where the carbon-bearing species resided in the dense aqueous phase without having to rely on petrophysical trapping mechanisms (structural and capillary). The enhanced oil production, net carbon storage, and storage security can be promoted by providing formate-based CCUS with more incentives (e.g., greater tax credit) in comparison to CO₂-based CCUS for EOR and the manufacture of chemicals and products. In establishing carbon storage incentive policies and regulations, policymakers should include alternative carbon carriers.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104257"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142528853","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":"Surrogate model optimization of vacuum pressure swing adsorption using a flexible metal organic framework with hysteretic sigmoidal isotherms","authors":"Yuya Takakura ,&nbsp;Suryateja Ravutla ,&nbsp;Jinsu Kim ,&nbsp;Keisuke Ikeda ,&nbsp;Hiroshi Kajiro ,&nbsp;Tomoyuki Yajima ,&nbsp;Junpei Fujiki ,&nbsp;Fani Boukouvala ,&nbsp;Matthew Realff ,&nbsp;Yoshiaki Kawajiri","doi":"10.1016/j.ijggc.2024.104260","DOIUrl":"10.1016/j.ijggc.2024.104260","url":null,"abstract":"<div><div>This study presents a process optimization study for a vacuum pressure swing adsorption (VPSA) process using a flexible metal-organic framework (MOF), which is gaining attention as a material to realize energy-efficient carbon dioxide capture processes. Many flexible MOFs exhibit sigmoidal adsorption isotherms with hysteresis, posing a challenge for simulation and optimization using a rigorous process model. In this study, we employ surrogate model optimization, where surrogate models using machine-learning algorithms were constructed from simulation of 903 operating conditions generated by Latin hypercube sampling. The surrogate models with the best performance were identified from 18 different surrogate options considering four design variables—adsorption pressure, desorption pressure, adsorption time, and desorption time. Using the best surrogate models, a multi-objective optimization problem was solved to identify the Pareto front among recovery, energy consumption, and bed size factor. Our analysis identified a distinct characteristic of VPSA using a flexible-MOF where purity and recovery are hardly affected by the feed volume.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104260"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142424079","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":"Feasibility of carbon dioxide geological storage in abandoned coal mine: A fully coupled model with validated multi-physical interactions","authors":"Teng Teng ,&nbsp;Shiqiang Yang ,&nbsp;Peng Yi ,&nbsp;Shengli Yang ,&nbsp;Chaoyang Ren ,&nbsp;Guoliang Gao","doi":"10.1016/j.ijggc.2024.104256","DOIUrl":"10.1016/j.ijggc.2024.104256","url":null,"abstract":"<div><div>It has gained wide attention that Carbon dioxide (CO₂) is to be injected into abandoned coal mines for geological storage of CO₂-enhanced coalbed methane recovery. Although abundantly evidences in literature indicate that the injection of CO₂ will cause lots of interactions among the mechanical characteristics of coal and the properties of CO₂ flow, further studies on these multi-physical interactions are still necessary. In this work, a series of laboratory experiments to elucidate the multi-physical interactions of CO₂ adsorption, softening effect of coal and the non-Darcy gas flow were conducted. Based on the experimental results, theoretical and empirical models to describe these coal-CO₂ interactions were meticulously proposed and validated, the results turned out to be satisfactory. Consequently, the compressive strength and elasticity modulus of coal decrease exponentially with the increased injection CO₂ pressure. The gas flow in coal obeys the Izbash non-Darcy model, and coal permeability can be well modified by the volumetric stress. By taking these coal-CO₂ interactions into account, this study established of a fully coupled model for coal deformation and CO₂ conservation. The model was then implemented into the numerical simulations of CO₂ storage in abandoned coal mine by using the finite element method. A series of scenario-based numerical simulations was conducted to investigate the feasibility and limitation of CO₂ storage in abandoned coal mine. The conducted experiments, models and numerical simulation will offer implications on the multi-physical interactions between coal and gas especially in CO₂ storage in abandoned coal mines.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"138 ","pages":"Article 104256"},"PeriodicalIF":4.6,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142528852","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}