Pub Date : 2026-03-01Epub Date: 2025-12-22DOI: 10.1016/j.geoen.2025.214346
Zhenpeng Cui , Bo Feng , Siqing He , Zheng Liu
{"title":"Corrigendum to ‘Numerical modeling of the mechanical-chemical coupling effects of acid fracturing on carbonate geothermal reservoir: A case study of the Well D22 in Xiong'an New Area, China’ [Geoenergy Sci. Eng. Volume 257, Part B, February 2026, 214276]","authors":"Zhenpeng Cui , Bo Feng , Siqing He , Zheng Liu","doi":"10.1016/j.geoen.2025.214346","DOIUrl":"10.1016/j.geoen.2025.214346","url":null,"abstract":"","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"258 ","pages":"Article 214346"},"PeriodicalIF":4.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145926362","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-03-01Epub Date: 2025-12-09DOI: 10.1016/j.geoen.2025.214339
Subhash C. Ayirala, Salah H. AlSaleh, Zuhair Al-Yousef, Abdullah Boqmi, Mustafa Satrawi, Jinxun Wang, Ali A. AlYousef
<div><div>Substantial volumes of produced water are being generated from oil & gas fields worldwide. If this produced water can be treated for reuse as low salinity injection water, it becomes a game changer to promote sustainability in IOR/EOR projects. In this study, the low salinity treated produced water obtained from zero liquid discharge (ZLD) technology has been used to evaluate the potential of recycled produced water in polymer flooding, gel- and foam-based mobility control processes.</div><div>Both static and dynamic tests were conducted at ambient and elevated temperatures using high salinity injection water (HSIW) and treated produced water (TPW). Rheometer was used to determine the viscosity characteristics of sulfonated polyacrylamide polymer solutions at 25<sup>o</sup>C and 75<sup>o</sup>C. Static glass bottles tests were conducted with gel solutions formulated using 3000 ppm sulfonated polyacrylamide and 150 ppm Cr (III) crosslinker at 95<sup>o</sup>C to determine the gel strength. Foam half-life times were measured to assess the foam stability. Finally, a core flood was conducted to evaluate the incremental oil recovery potential of using treated produced water in polymer flooding.</div><div>The results demonstrated that the polymer concentrations are reduced by about 8-times (from 2000 ppm to 250 ppm) to achieve the same viscosity in TPW as HSIW to significantly lower the polymer consumption requirements. The gelation times of the gel in HSIW was one to 2 h, while that of the gel in TPW was one to two days. Such considerable elongation of gelation time obtained with treated produced water would favorably deliver the gel deep into reservoir to achieve more efficient conformance improvement. The foam generated using the treated produced water showed at least 10-times longer foam half-life than that produced using the high salinity injection water. The core flood results conducted using 250 ppm polymer in treated produced water showed about 18 % total incremental oil recovery after high salinity water injection. Also, there was no impact of H<sub>2</sub>S scavenging chemical derivatives found in TPW on the performance of polymer, polymer gel, and foaming surfactants used in this study. These findings clearly demonstrate the promising potential of treated produced water in different IOR/EOR processes to lower chemical concentrations and achieve better mobility control/conformance improvement for higher oil recovery.</div><div>The novelty is that this study evaluates, for the first time, the beneficial impact of using the treated produced water obtained from a ZLD field pilot “as is” in different mobility control processes involving polymer, gels, and foams. There were also not that many studies in the literature that directly evaluated the product water streams obtained from produced water desalination field pilots to determine their synergistic effects with IOR/EOR agents and improved oil recovery. The recycling of produced wat
{"title":"Experimental evaluation of using treated produced water for mobility control and improved oil recovery in carbonates","authors":"Subhash C. Ayirala, Salah H. AlSaleh, Zuhair Al-Yousef, Abdullah Boqmi, Mustafa Satrawi, Jinxun Wang, Ali A. AlYousef","doi":"10.1016/j.geoen.2025.214339","DOIUrl":"10.1016/j.geoen.2025.214339","url":null,"abstract":"<div><div>Substantial volumes of produced water are being generated from oil & gas fields worldwide. If this produced water can be treated for reuse as low salinity injection water, it becomes a game changer to promote sustainability in IOR/EOR projects. In this study, the low salinity treated produced water obtained from zero liquid discharge (ZLD) technology has been used to evaluate the potential of recycled produced water in polymer flooding, gel- and foam-based mobility control processes.</div><div>Both static and dynamic tests were conducted at ambient and elevated temperatures using high salinity injection water (HSIW) and treated produced water (TPW). Rheometer was used to determine the viscosity characteristics of sulfonated polyacrylamide polymer solutions at 25<sup>o</sup>C and 75<sup>o</sup>C. Static glass bottles tests were conducted with gel solutions formulated using 3000 ppm sulfonated polyacrylamide and 150 ppm Cr (III) crosslinker at 95<sup>o</sup>C to determine the gel strength. Foam half-life times were measured to assess the foam stability. Finally, a core flood was conducted to evaluate the incremental oil recovery potential of using treated produced water in polymer flooding.</div><div>The results demonstrated that the polymer concentrations are reduced by about 8-times (from 2000 ppm to 250 ppm) to achieve the same viscosity in TPW as HSIW to significantly lower the polymer consumption requirements. The gelation times of the gel in HSIW was one to 2 h, while that of the gel in TPW was one to two days. Such considerable elongation of gelation time obtained with treated produced water would favorably deliver the gel deep into reservoir to achieve more efficient conformance improvement. The foam generated using the treated produced water showed at least 10-times longer foam half-life than that produced using the high salinity injection water. The core flood results conducted using 250 ppm polymer in treated produced water showed about 18 % total incremental oil recovery after high salinity water injection. Also, there was no impact of H<sub>2</sub>S scavenging chemical derivatives found in TPW on the performance of polymer, polymer gel, and foaming surfactants used in this study. These findings clearly demonstrate the promising potential of treated produced water in different IOR/EOR processes to lower chemical concentrations and achieve better mobility control/conformance improvement for higher oil recovery.</div><div>The novelty is that this study evaluates, for the first time, the beneficial impact of using the treated produced water obtained from a ZLD field pilot “as is” in different mobility control processes involving polymer, gels, and foams. There were also not that many studies in the literature that directly evaluated the product water streams obtained from produced water desalination field pilots to determine their synergistic effects with IOR/EOR agents and improved oil recovery. The recycling of produced wat","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"258 ","pages":"Article 214339"},"PeriodicalIF":4.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145926364","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-03-01Epub Date: 2025-12-05DOI: 10.1016/j.geoen.2025.214307
Jingyu Qu , Han Zhu , Qing Wang , Xiaofeng Sun , Tie Yan
As ultra-deep and 10,000-m-class wells become more prevalent, efficient cuttings transport in upper large-diameter sections poses a key challenge. To address this challenge, this study presents a method to determine the minimum flow rate (MFR) required for effective cuttings transport under both direct circulation (DC) and reverse circulation (RC) drilling conditions. The analysis begins with a force balance analysis of cuttings in non-Newtonian drilling fluids, modeled using both power-law and Herschel–Bulkley rheological frameworks. The relationship between drag coefficient and fluid rheological parameters is systematically examined, and the critical transport velocity is determined through drag force analysis. Based on this framework, iterative computational models are developed for both circulation modes to calculate the MFR required. Field data from two representative 10,000 m-class ultra-deep wells (SDTK-1 and SDCK-1) are used for sensitivity analysis on key parameters, including cuttings size, density, consistency coefficient, flow behavior index, yield stress, and drilling depth. Results show that RC significantly reduces the required flow rate, minimizes the number of circulation cycles, and enhances cuttings transport efficiency compared with conventional DC. These advantages are especially prominent in large-diameter sections, where RC demonstrates superior adaptability to variations in fluid rheology, leading to substantial reductions in flow rate. The proposed method provides both theoretical guidance and practical value for optimizing drilling operations of ultra-deep wells with upper large-diameter sections.
{"title":"A method for determining minimum flow rate for cuttings transport in upper large-diameter section of ultra-deep wells","authors":"Jingyu Qu , Han Zhu , Qing Wang , Xiaofeng Sun , Tie Yan","doi":"10.1016/j.geoen.2025.214307","DOIUrl":"10.1016/j.geoen.2025.214307","url":null,"abstract":"<div><div>As ultra-deep and 10,000-m-class wells become more prevalent, efficient cuttings transport in upper large-diameter sections poses a key challenge. To address this challenge, this study presents a method to determine the minimum flow rate (MFR) required for effective cuttings transport under both direct circulation (DC) and reverse circulation (RC) drilling conditions. The analysis begins with a force balance analysis of cuttings in non-Newtonian drilling fluids, modeled using both power-law and Herschel–Bulkley rheological frameworks. The relationship between drag coefficient and fluid rheological parameters is systematically examined, and the critical transport velocity is determined through drag force analysis. Based on this framework, iterative computational models are developed for both circulation modes to calculate the MFR required. Field data from two representative 10,000 m-class ultra-deep wells (SDTK-1 and SDCK-1) are used for sensitivity analysis on key parameters, including cuttings size, density, consistency coefficient, flow behavior index, yield stress, and drilling depth. Results show that RC significantly reduces the required flow rate, minimizes the number of circulation cycles, and enhances cuttings transport efficiency compared with conventional DC. These advantages are especially prominent in large-diameter sections, where RC demonstrates superior adaptability to variations in fluid rheology, leading to substantial reductions in flow rate. The proposed method provides both theoretical guidance and practical value for optimizing drilling operations of ultra-deep wells with upper large-diameter sections.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"258 ","pages":"Article 214307"},"PeriodicalIF":4.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145685877","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Polylactic acid (PLA) diverters have been extensively applied in fluid diversion treatments to create temporary flow barriers and ensure uniform treatment. Because PLA diverters tend to gradually hydrolyze in aqueous solutions into lactic acids through ester bond cleavage, their diversion performance is influenced by the rate of their hydrolytic degradation, which strongly depends on particle size, pH levels, and temperature. The effects of these factors on the degradation rate of commercial PLA diverters remain underexplored. In this study we systematically characterize the effects of particle size, solution pH, and temperature on the hydrolysis rate of PLA diverters in aqueous media. We found that the size of diverter greatly affected its degradation rates, and the extent of this effect depended on the solution pH. The effects of solution pH were also strongly correlated with the shapes of diverters. Higher temperatures greatly accelerated hydrolysis and reduced induction periods. The gathered hydrolysis data aligns closely with a previously established kinetic model. The kinetic rate constants varied only slightly with diverter size but were strongly affected by solution pH and temperature. These insights enhance our understanding of the PLA diverter's degradation behaviors under conditions relevant to various downhole environments and provide guidance for optimizing its field performance.
{"title":"Effects of geometry and degradation conditions on the aqueous hydrolysis of polylactic acid diverters","authors":"Xiaoshuang Chen , Murtaza Ziauddin , Cheng Wu , Yingda Lu","doi":"10.1016/j.geoen.2025.214324","DOIUrl":"10.1016/j.geoen.2025.214324","url":null,"abstract":"<div><div>Polylactic acid (PLA) diverters have been extensively applied in fluid diversion treatments to create temporary flow barriers and ensure uniform treatment. Because PLA diverters tend to gradually hydrolyze in aqueous solutions into lactic acids through ester bond cleavage, their diversion performance is influenced by the rate of their hydrolytic degradation, which strongly depends on particle size, pH levels, and temperature. The effects of these factors on the degradation rate of commercial PLA diverters remain underexplored. In this study we systematically characterize the effects of particle size, solution pH, and temperature on the hydrolysis rate of PLA diverters in aqueous media. We found that the size of diverter greatly affected its degradation rates, and the extent of this effect depended on the solution pH. The effects of solution pH were also strongly correlated with the shapes of diverters. Higher temperatures greatly accelerated hydrolysis and reduced induction periods. The gathered hydrolysis data aligns closely with a previously established kinetic model. The kinetic rate constants varied only slightly with diverter size but were strongly affected by solution pH and temperature. These insights enhance our understanding of the PLA diverter's degradation behaviors under conditions relevant to various downhole environments and provide guidance for optimizing its field performance.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"258 ","pages":"Article 214324"},"PeriodicalIF":4.6,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145790949","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-02-01Epub Date: 2025-08-27DOI: 10.1016/j.geoen.2025.214176
Lei Hou , Jiangfeng Luo , Egor Dontsov , Zhengxin Zhang , Alexander Valov , Fengshou Zhang , Xiaobing Bian , Liang Fu
Accurately predicting fracturing pressure is critical for optimizing the safety and efficiency of hydraulic fracturing operations, particularly in newly developed blocks where data scarcity poses significant challenges. Traditional machine learning methods require large, high-quality datasets to train algorithms. To address these limitations, this study presents physics-boosted transfer learning frameworks designed to enhance fracturing pressure prediction in data-scarce scenarios. By integrating a gated recurrent unit (GRU) deep learning model with physical modeling principles, three transfer learning frameworks were developed and evaluated, including a pure data-driven framework, a hybrid-modelling framework, and a physics-informed framework. Field data from only three shale gas wells were utilized to train the GRU algorithm – simulating real-field data-scarcity scenarios. Fine-tuning technologies are optimized based on the pure data-driven framework. The physics-informed framework demonstrated superior performance, achieving root mean square errors (RMSE) as low as 2–3 MPa, significantly outperforming both the pure data-driven and hybrid frameworks in terms of accuracy, stability, and adaptability. By bridging the gap between data-driven methods and physical modeling, this new framework offers a robust solution, for improving operational safety and cost-effectiveness in hydraulic fracturing, particularly under data-scarce conditions.
{"title":"A physics-boosted transfer learning framework for fracturing pressure prediction with scarce data","authors":"Lei Hou , Jiangfeng Luo , Egor Dontsov , Zhengxin Zhang , Alexander Valov , Fengshou Zhang , Xiaobing Bian , Liang Fu","doi":"10.1016/j.geoen.2025.214176","DOIUrl":"10.1016/j.geoen.2025.214176","url":null,"abstract":"<div><div>Accurately predicting fracturing pressure is critical for optimizing the safety and efficiency of hydraulic fracturing operations, particularly in newly developed blocks where data scarcity poses significant challenges. Traditional machine learning methods require large, high-quality datasets to train algorithms. To address these limitations, this study presents physics-boosted transfer learning frameworks designed to enhance fracturing pressure prediction in data-scarce scenarios. By integrating a gated recurrent unit (GRU) deep learning model with physical modeling principles, three transfer learning frameworks were developed and evaluated, including a pure data-driven framework, a hybrid-modelling framework, and a physics-informed framework. Field data from only three shale gas wells were utilized to train the GRU algorithm – simulating real-field data-scarcity scenarios. Fine-tuning technologies are optimized based on the pure data-driven framework. The physics-informed framework demonstrated superior performance, achieving root mean square errors (RMSE) as low as 2–3 MPa, significantly outperforming both the pure data-driven and hybrid frameworks in terms of accuracy, stability, and adaptability. By bridging the gap between data-driven methods and physical modeling, this new framework offers a robust solution, for improving operational safety and cost-effectiveness in hydraulic fracturing, particularly under data-scarce conditions.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"257 ","pages":"Article 214176"},"PeriodicalIF":4.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144989917","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-02-01Epub Date: 2025-10-02DOI: 10.1016/j.geoen.2025.214241
Qiang Li , Zhengfu Ning , Yuheng Yang , Xiqian Zheng , Jun Li , Zejiang Jia
Carbonate reservoirs, critical to global hydrocarbon resources, face development challenges due to heterogeneous multi-scale pore structures, resulting in severe water channeling and low recovery rates (<30 %) during conventional waterflooding. While direct current (DC) electric field-assisted oil displacement offers efficient, cost-effective, and eco-friendly potential, its microscopic mechanisms remain underexplored. This study combines multi-scale pore characterization and core flooding experiments to systematically evaluate electric field effects on multiphase flow in heterogeneous reservoirs, emphasizing pore-scale electro-osmosis–electrophoresis synergy. Analyses of a calcite-dominated carbonate formation (95 % calcite, inter/intragranular porosity, poor connectivity) using scanning electron microscope (SEM), thin-section petrography, mercury intrusion, and nuclear magnetic resonance spectroscopy (NMR) revealed limited conventional waterflooding performance (25 %–28 % recovery), primarily mobilizing macropores (>100 μm). Applying a 20V DC electric field increased recovery by 10.6 %, with an optimized “post-water-free electric drive” strategy adding 7.57 % incremental recovery. Even in long heterogeneous cores, a sustained 4.7 % recovery gain demonstrated field applicability. NMR confirmed enhanced oil mobilization in mesopores (10–100 μm), expanding accessible pore networks. Kinetic analysis identified dual mechanisms: Optimal displacement pressure gradients (0.5–0.6 MPa/cm) stabilized injection pressure, suppressed water channeling, and delayed water breakthrough; Intensified electro-osmosis promoted ion-directed migration, dynamically stabilizing pressure fields while reducing water consumption by ∼10 %. These processes synergistically improved displacement efficiency across pore scales. The study demonstrates DC electric fields effectively regulate multi-scale pore utilization and optimize seepage field distribution, providing mechanistic insights and engineering guidelines for carbonate reservoir development. By enhancing recovery efficiency while reducing water use and injection energy requirements, this approach demonstrates potential for low-carbon hydrocarbon recovery, supporting sustainable energy transitions.
{"title":"Analysis of oil recovery efficiency based on nuclear magnetic resonance in porous media under the action of electric field: insights from microstructure and pore scale analysis","authors":"Qiang Li , Zhengfu Ning , Yuheng Yang , Xiqian Zheng , Jun Li , Zejiang Jia","doi":"10.1016/j.geoen.2025.214241","DOIUrl":"10.1016/j.geoen.2025.214241","url":null,"abstract":"<div><div>Carbonate reservoirs, critical to global hydrocarbon resources, face development challenges due to heterogeneous multi-scale pore structures, resulting in severe water channeling and low recovery rates (<30 %) during conventional waterflooding. While direct current (DC) electric field-assisted oil displacement offers efficient, cost-effective, and eco-friendly potential, its microscopic mechanisms remain underexplored. This study combines multi-scale pore characterization and core flooding experiments to systematically evaluate electric field effects on multiphase flow in heterogeneous reservoirs, emphasizing pore-scale electro-osmosis–electrophoresis synergy. Analyses of a calcite-dominated carbonate formation (95 % calcite, inter/intragranular porosity, poor connectivity) using scanning electron microscope (SEM), thin-section petrography, mercury intrusion, and nuclear magnetic resonance spectroscopy (NMR) revealed limited conventional waterflooding performance (25 %–28 % recovery), primarily mobilizing macropores (>100 μm). Applying a 20V DC electric field increased recovery by 10.6 %, with an optimized “post-water-free electric drive” strategy adding 7.57 % incremental recovery. Even in long heterogeneous cores, a sustained 4.7 % recovery gain demonstrated field applicability. NMR confirmed enhanced oil mobilization in mesopores (10–100 μm), expanding accessible pore networks. Kinetic analysis identified dual mechanisms: Optimal displacement pressure gradients (0.5–0.6 MPa/cm) stabilized injection pressure, suppressed water channeling, and delayed water breakthrough; Intensified electro-osmosis promoted ion-directed migration, dynamically stabilizing pressure fields while reducing water consumption by ∼10 %. These processes synergistically improved displacement efficiency across pore scales. The study demonstrates DC electric fields effectively regulate multi-scale pore utilization and optimize seepage field distribution, providing mechanistic insights and engineering guidelines for carbonate reservoir development. By enhancing recovery efficiency while reducing water use and injection energy requirements, this approach demonstrates potential for low-carbon hydrocarbon recovery, supporting sustainable energy transitions.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"257 ","pages":"Article 214241"},"PeriodicalIF":4.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145267132","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-02-01Epub Date: 2025-09-18DOI: 10.1016/j.geoen.2025.214224
Yuanxiu Sun , Yuanyuan Li , Yangfan Tang , Shuai Xie , Yue Wang , Songqi Li
With the escalating global demand for clean energy and the mounting pressure of carbon emission reduction, the synergistic approach of carbon dioxide sequestration in geothermal mining has gradually emerged as the current research hotspots. Studying this technology under multi-field coupling condition is crucial for efficient geothermal mining and carbon dioxide sequestration. From the perspective of multi-physical field coupling, the synergistic storage technology and optimization path of carbon dioxide geothermal mining are investigated, and the research progress in this field is also clarified.Initially, the mechanism of geothermal mining and sequestration with carbon dioxide are introduced. On this basis, we further explore the effects of various factors on the synergistic carbon sequestration in geothermal mining under a multi-field coupling mechanism. Finally, three different optimization methods based on injection-production schemes, reservoir structure and numerical simulation are proposed. Furthermore, the current challenges and future development directions of the synergistic sequestration technology for geothermal mining with carbon dioxide as the medium are summarized in this paper. The research presented in this paper provides vital theoretical basis and technical support for promoting the sustainable development of geothermal resources and accelerating the carbon dioxide emission reduction.
{"title":"Research progress of geothermal mining and carbon dioxide sequestration: multi-field coupling effect, synergy and optimization method","authors":"Yuanxiu Sun , Yuanyuan Li , Yangfan Tang , Shuai Xie , Yue Wang , Songqi Li","doi":"10.1016/j.geoen.2025.214224","DOIUrl":"10.1016/j.geoen.2025.214224","url":null,"abstract":"<div><div>With the escalating global demand for clean energy and the mounting pressure of carbon emission reduction, the synergistic approach of carbon dioxide sequestration in geothermal mining has gradually emerged as the current research hotspots. Studying this technology under multi-field coupling condition is crucial for efficient geothermal mining and carbon dioxide sequestration. From the perspective of multi-physical field coupling, the synergistic storage technology and optimization path of carbon dioxide geothermal mining are investigated, and the research progress in this field is also clarified.Initially, the mechanism of geothermal mining and sequestration with carbon dioxide are introduced. On this basis, we further explore the effects of various factors on the synergistic carbon sequestration in geothermal mining under a multi-field coupling mechanism. Finally, three different optimization methods based on injection-production schemes, reservoir structure and numerical simulation are proposed. Furthermore, the current challenges and future development directions of the synergistic sequestration technology for geothermal mining with carbon dioxide as the medium are summarized in this paper. The research presented in this paper provides vital theoretical basis and technical support for promoting the sustainable development of geothermal resources and accelerating the carbon dioxide emission reduction.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"257 ","pages":"Article 214224"},"PeriodicalIF":4.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145109726","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-02-01Epub Date: 2025-09-14DOI: 10.1016/j.geoen.2025.214209
Xiang Yan , Caili Dai , Yongping Huang , Siwei Meng , Xu Jin , He Liu , Bin Yuan , Ming Chen , Yining Wu
Hydraulic fracturing plays a pivotal role in developing deep/ultra-deep oil and gas reservoirs. The high in-situ stress in deep/ultra-deep reservoirs results in narrow fracture apertures, which increases frictional resistance between proppants and fracture walls. This hinders proppant migration to the deeper regions of fractures for effective support, necessitating fracturing fluids with enhanced sand-carrying capabilities. In this study, two types of polymers capable of forming physically crosslinked networks through supramolecular interactions were synthesized. When crosslinked with organic zirconium, they form a supramolecular reinforced gel fracturing fluid. The fracturing fluid exhibits high strength, excellent shear recovery, and strong water-binding capacity, which allows the lubricating liquid film formed by the fracturing fluid on the fracture surface to maintain stability under ultra-high temperature conditions in ultra-deep reservoirs, thereby effectively reducing the frictional resistance between the proppant and the fracture walls. Data from the tribological experiment show that under the lubrication of the supramolecular reinforced gel fracturing fluid, the coefficient of friction (COF) of the proppant-fracture wall contacts is 0.48, which is 15.23 % lower than that of partially hydrolyzed polyacrylamide (HPAM) gel fracturing fluid. The relationship between the lubricating performance of the fracturing fluid and its sand-carrying ability was studied using the computational fluid dynamics-discrete element method (CFD-DEM) simulation approach. Under the lubrication effect of the fracturing fluid, the deep migration rate of the proppant (defined as the ratio of the number of proppants flowing out of the fracture to the total number of proppants) significantly increased from 7.16 % at a COF of 0.8–69.02 % at a COF of 0.05. This indicates that improved lubricating performance of the fracturing fluid enhances the proppant's ability to migrate into the deeper regions of the fracture.
{"title":"Supramolecular reinforced gel fracturing fluid applied in ultra-deep reservoirs: Mechanism research of sand-carrying under fracturing fluid lubrication","authors":"Xiang Yan , Caili Dai , Yongping Huang , Siwei Meng , Xu Jin , He Liu , Bin Yuan , Ming Chen , Yining Wu","doi":"10.1016/j.geoen.2025.214209","DOIUrl":"10.1016/j.geoen.2025.214209","url":null,"abstract":"<div><div>Hydraulic fracturing plays a pivotal role in developing deep/ultra-deep oil and gas reservoirs. The high in-situ stress in deep/ultra-deep reservoirs results in narrow fracture apertures, which increases frictional resistance between proppants and fracture walls. This hinders proppant migration to the deeper regions of fractures for effective support, necessitating fracturing fluids with enhanced sand-carrying capabilities. In this study, two types of polymers capable of forming physically crosslinked networks through supramolecular interactions were synthesized. When crosslinked with organic zirconium, they form a supramolecular reinforced gel fracturing fluid. The fracturing fluid exhibits high strength, excellent shear recovery, and strong water-binding capacity, which allows the lubricating liquid film formed by the fracturing fluid on the fracture surface to maintain stability under ultra-high temperature conditions in ultra-deep reservoirs, thereby effectively reducing the frictional resistance between the proppant and the fracture walls. Data from the tribological experiment show that under the lubrication of the supramolecular reinforced gel fracturing fluid, the coefficient of friction (COF) of the proppant-fracture wall contacts is 0.48, which is 15.23 % lower than that of partially hydrolyzed polyacrylamide (HPAM) gel fracturing fluid. The relationship between the lubricating performance of the fracturing fluid and its sand-carrying ability was studied using the computational fluid dynamics-discrete element method (CFD-DEM) simulation approach. Under the lubrication effect of the fracturing fluid, the deep migration rate of the proppant (defined as the ratio of the number of proppants flowing out of the fracture to the total number of proppants) significantly increased from 7.16 % at a COF of 0.8–69.02 % at a COF of 0.05. This indicates that improved lubricating performance of the fracturing fluid enhances the proppant's ability to migrate into the deeper regions of the fracture.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"257 ","pages":"Article 214209"},"PeriodicalIF":4.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145106180","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-02-01Epub Date: 2025-09-16DOI: 10.1016/j.geoen.2025.214222
Hongbin Yang , Haocong Li , Hao Xu , Ruichao Wang , Yubin Zhang , Luyao Xing , Xin Chen , Liang Peng , Wanli Kang , Bauyrzhan Sarsenbekuly
CO2 foam flooding is an effective enhanced oil recovery (EOR) technique that has been extensively studied for development of low-permeability reservoirs. However, during its application, poor foam stability often leads to severe gas channeling, resulting in lower recovery. In order to improve the foam stability, a CO2 foam system was constructed by using fluorescent nano polymer microspheres (PARC(Flu-Ac)-5) and anionic surfactant sodium α-alkene sulfonate (AOS). The macroscopic and microscopic stability of the CO2 foam system stabilized by PARC(Flu-Ac)-5 was investigated through its rheological properties, adsorption characteristics, and microscopic morphology. Furthermore, the sweep range of different foam systems and the stability of the foam in the channel were explored through the microscopic visualization model. Finally, the plugging and oil displacement performance of the CO2 foam system stabilized by fluorescent nano polymer microspheres was evaluated through dynamic core flooding experiments conducted under CO2 flooding reservoir conditions. Thus, the oil displacement mechanism of fluorescent nano polymer microspheres stabilizing CO2 foam was revealed. The experimental results demonstrate that PARC(Flu-Ac)-5 microspheres greatly enhance the stability of CO2 foam by adsorbing at the gas-liquid interface. It remains stable for 30 min when formed with 5 % oil content. The microspheres' distinctive elastic deformation characteristics enable their migration and subsequent plugging of the pores following foam rupture, thereby establishing a dual anti-gas channeling mechanism. The total recovery of CO2 foam system stabilized by fluorescent nano polymer microspheres is 46.71 %. The oil displacement effect is better than that of the single AOS foam system, and the total recovery rate is increased by 12.02 %. By adsorbing at the gas-liquid interface of foam liquid film, PARC(Flu-Ac)-5, acting as a foam stabilizer, enhances both the stability and oil resistance of foam within porous media. This adsorption behavior thereby enabling the foam to maintain its integrity upon encountering crude oil and preventing foam coalescence and defoaming. Concurrently, under the Jamin effect of the foam, the foam preferentially occupies the pore space in high permeability layers, and the injected fluid is diverted toward unswept regions following the plugging of high permeability pathways. Consequently, the sweep range and the driving ability of the subsequent foam to enter the blind end are increased, and the recovery rate of crude oil is improved. This work lays a theoretical foundation for the field application of polymer microspheres stabilized CO2 foam system.
{"title":"Enhanced CO2 foam stabilization with fluorescent nano polymer microspheres for improved oil recovery: Insights from microscopic and macroscopic displacement studies","authors":"Hongbin Yang , Haocong Li , Hao Xu , Ruichao Wang , Yubin Zhang , Luyao Xing , Xin Chen , Liang Peng , Wanli Kang , Bauyrzhan Sarsenbekuly","doi":"10.1016/j.geoen.2025.214222","DOIUrl":"10.1016/j.geoen.2025.214222","url":null,"abstract":"<div><div>CO<sub>2</sub> foam flooding is an effective enhanced oil recovery (EOR) technique that has been extensively studied for development of low-permeability reservoirs. However, during its application, poor foam stability often leads to severe gas channeling, resulting in lower recovery. In order to improve the foam stability, a CO<sub>2</sub> foam system was constructed by using fluorescent nano polymer microspheres (PARC(Flu-Ac)-5) and anionic surfactant sodium α-alkene sulfonate (AOS). The macroscopic and microscopic stability of the CO<sub>2</sub> foam system stabilized by PARC(Flu-Ac)-5 was investigated through its rheological properties, adsorption characteristics, and microscopic morphology. Furthermore, the sweep range of different foam systems and the stability of the foam in the channel were explored through the microscopic visualization model. Finally, the plugging and oil displacement performance of the CO<sub>2</sub> foam system stabilized by fluorescent nano polymer microspheres was evaluated through dynamic core flooding experiments conducted under CO<sub>2</sub> flooding reservoir conditions. Thus, the oil displacement mechanism of fluorescent nano polymer microspheres stabilizing CO<sub>2</sub> foam was revealed. The experimental results demonstrate that PARC(Flu-Ac)-5 microspheres greatly enhance the stability of CO<sub>2</sub> foam by adsorbing at the gas-liquid interface. It remains stable for 30 min when formed with 5 % oil content. The microspheres' distinctive elastic deformation characteristics enable their migration and subsequent plugging of the pores following foam rupture, thereby establishing a dual anti-gas channeling mechanism. The total recovery of CO<sub>2</sub> foam system stabilized by fluorescent nano polymer microspheres is 46.71 %. The oil displacement effect is better than that of the single AOS foam system, and the total recovery rate is increased by 12.02 %. By adsorbing at the gas-liquid interface of foam liquid film, PARC(Flu-Ac)-5, acting as a foam stabilizer, enhances both the stability and oil resistance of foam within porous media. This adsorption behavior thereby enabling the foam to maintain its integrity upon encountering crude oil and preventing foam coalescence and defoaming. Concurrently, under the Jamin effect of the foam, the foam preferentially occupies the pore space in high permeability layers, and the injected fluid is diverted toward unswept regions following the plugging of high permeability pathways. Consequently, the sweep range and the driving ability of the subsequent foam to enter the blind end are increased, and the recovery rate of crude oil is improved. This work lays a theoretical foundation for the field application of polymer microspheres stabilized CO<sub>2</sub> foam system.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"257 ","pages":"Article 214222"},"PeriodicalIF":4.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145106179","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2026-02-01Epub Date: 2025-09-17DOI: 10.1016/j.geoen.2025.214221
Shichun Yan , Mingming Zheng , Zurui Wu , Yawei Zhang , Yunpeng Hu , TianLe Liu , Guosheng Jiang
This study investigates the impact of gas hydrate decomposition on cement sheath integrity in deepwater wells encountering gas hydrate-bearing sediments (GHBS) using a novel coupled TOUGH + HYDRATE (T + H) and Particle Flow Code (PFC) model. The model simulates cement penetration, hydrate decomposition, and reverse invasion fluid migration, quantifying the collective effects on sheath integrity through crack development. Parametric studies show that hydrate dissociation extended up to 0.20 m, increase the cement sheath crack ratio by up to 40.64 %, and reduce compressive strength by up to 56.5 %. These findings evaluate the physical responses of the sediment-cement system under varying conditions, providing key insights for optimizing cementing strategies in GHBS.
{"title":"Hydrate decomposition and its influence on cement sheath strength in cementing process","authors":"Shichun Yan , Mingming Zheng , Zurui Wu , Yawei Zhang , Yunpeng Hu , TianLe Liu , Guosheng Jiang","doi":"10.1016/j.geoen.2025.214221","DOIUrl":"10.1016/j.geoen.2025.214221","url":null,"abstract":"<div><div>This study investigates the impact of gas hydrate decomposition on cement sheath integrity in deepwater wells encountering gas hydrate-bearing sediments (GHBS) using a novel coupled TOUGH + HYDRATE (T + H) and Particle Flow Code (PFC) model. The model simulates cement penetration, hydrate decomposition, and reverse invasion fluid migration, quantifying the collective effects on sheath integrity through crack development. Parametric studies show that hydrate dissociation extended up to 0.20 m, increase the cement sheath crack ratio by up to 40.64 %, and reduce compressive strength by up to 56.5 %. These findings evaluate the physical responses of the sediment-cement system under varying conditions, providing key insights for optimizing cementing strategies in GHBS.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"257 ","pages":"Article 214221"},"PeriodicalIF":4.6,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145106177","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：