Geoenergy Science and Engineering最新文献

{"title":"Improved MER algorithm for lost circulation detection using transient pressure waves","authors":"Zhongxi Zhu ,&nbsp;Kangkai Yan ,&nbsp;Wanneng Lei ,&nbsp;Lei Cao","doi":"10.1016/j.geoen.2024.213467","DOIUrl":"10.1016/j.geoen.2024.213467","url":null,"abstract":"<div><div>In order to solve the difficult problem of locating the leakage layer in the bare eye well section during drilling, this study proposes a transient pressure wave well leakage detection method based on the modified energy ratio (MER) analysis. The method makes clever use of the similarity between the transient pressure waveform and the first arrival of the microseismic signal, and accurately captures the sudden change moments of the pressure wave to obtain the time difference of the signal through the MER method, and combines with the wave velocity of the pressure wave to achieve the precise location of the leakage layer. To address the problem of high noise content in transient pressure wave signals, this study proposes an improved variational modal decomposition (VMD) adaptive denoising method, which effectively removes the noise components and retains the key features of the signals to the maximum extent, and the signal-to-noise ratio of the signal after noise reduction can be up to 15.64. The experimental results show that the leaky layer localisation error of the method ranges from 0.13% to 5.30%. Under the same conditions, the accuracy of the MER localisation method is better than that of the wavelet mode maxima method, the frequency domain method and the short-time averaging/long-time averaging (STA/LTA) method, and the localisation error rate can be as low as 2.11%. The transient pressure wave well leakage detection method based on the improved MER algorithm provides a low-cost, high-precision and efficient solution for well leakage detection during drilling.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213467"},"PeriodicalIF":0.0,"publicationDate":"2024-11-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142578880","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}

{"title":"Nonlinear rub-impact characteristics of drillstring-wellbore and wear quantitative evaluation method","authors":"Feng Tang ,&nbsp;Yongsheng Liu ,&nbsp;Jianxin Xia ,&nbsp;Shangyu Yang ,&nbsp;Jianguo Lv","doi":"10.1016/j.geoen.2024.213466","DOIUrl":"10.1016/j.geoen.2024.213466","url":null,"abstract":"<div><div>Aiming at complex vibration behavior of drill string on drilling efficiency and safety in drilling engineering, this paper has been conducted on the nonlinear rub-impact characteristics and quantitative evaluation method of drill string. Firstly, a nonlinear dynamic model of the drill string was established, comprehensively considering the nonlinear contact between the drill string and casing, drilling fluid buoyancy, and damping effects. Then, the influence of driving speed, eccentricity, and drilling fluid density on the vibration response of the drill string was analyzed. Finally, a visualization method was proposed to characterize the random contact and collision between the drill string and casing. Based on this characterization, a dimensionless rub-impact index (RI) was defined to quantitatively evaluate the nonlinear rub-impact behavior between the drill string and casing. The results show that excessive high and low driving speeds can induce complex and unstable lateral motion trajectories of the drill string, accompanied by random and periodic rub-impact, significantly increasing the possibility of destructive lateral impacts between the drill string and casing. An increase in eccentricity leads to more frequent rub-impact between the drill string and casing. Specifically, when the eccentricity increases from 0.01 m to 0.02 m, the number of rub-impact occurrences rises sharply from 98,256 to 148,920, an increase of 51.6%. Moreover, although increasing the drilling fluid density complicates the vibration modes of the drill string, it effectively suppresses lateral vibrations, thereby protecting the wellbore. The visualization method can intuitively characterize the nonlinear rub-impact characteristics induced by the lateral vibrations of the drill string. The dimensionless rub-impact index (RI) based on rub-impact characterization accurately reflects the severity of the drill string-casing rub-impact. It can serve as an effective tool for assessing the degree of rub-impact. This facilitates a deeper understanding and analysis of the vibration characteristics of the drill string. Provide valuable references for drilling vibration control and optimization of drilling parameters.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213466"},"PeriodicalIF":0.0,"publicationDate":"2024-11-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142578878","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}

{"title":"CO2 sequestration wells sealing evaluation model: Jimusar depression, China as an example","authors":"Dian Wang ,&nbsp;Jun Li ,&nbsp;Wei Lian ,&nbsp;Xianbo Liu ,&nbsp;Juncheng Zhang ,&nbsp;Han Xiao","doi":"10.1016/j.geoen.2024.213439","DOIUrl":"10.1016/j.geoen.2024.213439","url":null,"abstract":"<div><div>Suitable geological sites for CO₂ sequestration often contain numerous existing wellbores, which have been identified as high-risk locations for CO₂ leakage. To investigate whether the pressure disturbances caused by CO₂ injection have the potential to drive the propagation of micro-annulus in nearby wells, this paper develops and validates a numerical simulation program, taking the Jimusar Depression in China as a case study. The results indicate that the phenomenon of formation overpressure caused by CO₂ injection occurs not only in the reservoir but also in the caprock. The pressure response of the caprock exhibits a lag, resulting in a dynamic inter-layer pressure difference, with a peak difference observed during the early stages of injection. As the distance from the injection well increases, the peak pressure difference decreases exponentially, with a maximum differential pressure of 1.33 MPa observed at well J172. The pressure difference around the well can drive fluid migration along the cement bonding surface, and excessive pressure differences can lead to changes in the stress state of the surface. When the stress state transitions from compression to tension, and the tensile stress exceeds the bonding strength, micro-annulus may propagate. When the cement curing shrinkage rate is zero, the minimum pressure difference for micro-annulus propagation at the cement-sheath formation interface in well J172 is 9.39 MPa, which is significantly higher than the peak formation pressure difference of 1.33 MPa around the well, indicating a low risk of micro-annulus propagation. The shrinkage of the cement upon curing will considerably lower the critical pressure for micro-annulus propagation. At a cement shrinkage rate of 0.15%, the propagation pressure for micro-annulus decreases to 1.0 MPa, indicating a higher risk of micro-annulus propagation. This study proposes a CO₂ sequestration well sealing assessment program, which confirms that under unfavorable conditions, CO₂ injection may induce the propagation of micro-annulus near the well. This research holds significant implications for the safety of wellbores at CO₂ sequestration sites, as well as for monitoring CO₂ plumes and pressure.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213439"},"PeriodicalIF":0.0,"publicationDate":"2024-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573060","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}

{"title":"A novel damage index for crack identification of a drilling riser during deployment based on the modal vibration energy flow","authors":"Xingkun Zhou ,&nbsp;Yan Li ,&nbsp;Yaning Dou ,&nbsp;Xiantao Zhang","doi":"10.1016/j.geoen.2024.213464","DOIUrl":"10.1016/j.geoen.2024.213464","url":null,"abstract":"<div><div>Early detection of structural damage especially small cracks in marine deepwater drilling risers is of paramount importance. Small cracks are always hard to detect because of weak vibration signals if using traditional damage indices, such as natural frequencies and mode shapes including modal displacements, cross-section slopes, and curvatures. Especially when the deepwater riser is during deployment, the variable suspension riser length and strong sea environment noise make the small crack identification more difficult. To address this problem, this study formulates a new concept of damage detection by integrating the vibration energy flow theory into the vibration-based damage detection (VDD) technique. A novel damage-sensitive feature (DSF) named modal vibration energy flow (MVEF) is established for detecting and locating the small cracks in deepwater drilling risers. The capability of the approach is verified by using the same riser model and the numerical results in the literature. The sensitivities versus crack positions and depths, variable suspension riser length, and sea noise are studied in detail. Results show that the proposed index MVEF is more sensitive than the classic traditional DSFs, i.e., modal slope, modal strain (or curvature), and modal strain energy. In total, the MVEF approach can accurately identify the small cracks and is robust against noise interference, suitable for detecting and locating small cracks in the deepwater drilling riser during deployment.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213464"},"PeriodicalIF":0.0,"publicationDate":"2024-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142659898","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}

{"title":"The characteristics of steam chamber expanding and the EOR mechanisms of tridimensional steam flooding (TSF) in thick heavy oil reservoirs","authors":"Xiangxing Yan ,&nbsp;Zhanxi Pang ,&nbsp;Dong Liu ,&nbsp;Bo Wang","doi":"10.1016/j.geoen.2024.213434","DOIUrl":"10.1016/j.geoen.2024.213434","url":null,"abstract":"<div><div>Aiming at the shortcoming of conventional steam flooding (<em>CSF</em>), tridimensional steam flooding (<em>TSF</em>) was proposed to expand the limited steam chamber and to enhance the low oil recovery in thick heavy oil reservoirs. In this paper, based on mechanisms of thermal recovery, two 3D experimental models were designed to investigate the evolution of steam chambers and production performance. A new method was proposed to utilize inflection point temperature and remaining oil saturation to identify utilizable ranges, hot water zones, and steam chambers. Then, based on the parameters of the indoor experiments, three numerical models were built to further study advantages of <em>TSF</em>. The results show that: i) Compared to <em>CSF</em>, <em>TSF</em> possesses a plumper steam chamber, a higher steam quality and a more stable displacement front; ii) The oil recovery of <em>TSF</em> can reach 52.85%, while it is only 43.31% for <em>CSF</em> at the same time; iii) At the end of <em>TSF</em>, the volume of steam chamber, low oil saturation zone, low pressure zone, and low viscosity zone is 3.08 times, 3.31 times, 1.61 times, and 1.55 times, respectively, compared to <em>CSF</em>, which demonstrates that <em>TSF</em> is effective. As a result, <em>TSF</em> can effectively expand steam chamber and enhance oil recovery in thick heavy oil reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213434"},"PeriodicalIF":0.0,"publicationDate":"2024-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142659895","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}

{"title":"Hybrid-driven MRF seismic inversion for gas sand identification: A case study in the Yinggehai Basin","authors":"Lingyuan Zhang,&nbsp;Hongbing Zhang,&nbsp;Xinyi Zhu,&nbsp;Fanxin Zeng,&nbsp;Xinjie Zhu","doi":"10.1016/j.geoen.2024.213463","DOIUrl":"10.1016/j.geoen.2024.213463","url":null,"abstract":"<div><div>The Yinggehai Basin displays anomalies characterized by heightened levels of temperature and pressure. It represents a depositional model of a submarine fan with gravity-driven flow, demonstrating significant lateral reservoir heterogeneity and intricate spatial distribution of the gas reservoir. Identifying gas formations using elastic parameters as indicators relies on stable seismic inversion results. This requires regularization to alleviate ill-posedness in the inverse problem and to construct model features of the subsurface medium. Markov Random Field (MRF)is an effective soft-constrained regularization method. It enhances the marginal features of inversion results by penalizing the objective function with the gradient of neighborhood points. However, the standard MRF method relies only on the parameter model-driven and has poor applicability in areas with strong lateral inhomogeneity or complex depositional processes. In this research paper, we propose a novel approach to seismic inversion that integrates MRF neighborhood drive and incorporates both seismic data and a parametric model. Multi-order MRF neighborhoods are constructed by using seismic data in the horizontal direction (including horizontal diagonal) and parametric model data in the vertical direction (including vertical diagonal). The model-driven results are also utilized to couple seismic data and improve the stability of the hybrid-driven MRF inversion. In addition, we select the P-impedance as the parameter for inversion due to its heightened sensitivity towards gas formation within the study region. Consequently, we utilize the inversion results to delineate the presence of sandstone in the target layer and discern any indications of gas formation. The implementation of this method in the field has demonstrated its capability to enhance the stability of inversion outcomes, effectively integrating the lateral consistency of seismic data with the vertical precision of parametric model data. This approach significantly improves reservoir heterogeneity characterization and enhances accuracy in identifying sandstone and gas.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213463"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573167","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}

{"title":"Cryogenic fracturing efficacy in granite rocks: Fracture toughness and brazilian test differences after elevated temperatures and liquid nitrogen exposure","authors":"Sotirios Nik Longinos,&nbsp;Randy Hazlett","doi":"10.1016/j.geoen.2024.213436","DOIUrl":"10.1016/j.geoen.2024.213436","url":null,"abstract":"<div><div>Hot dry rock (HDR) is a significant contingent as a thermal energy source. Due to its low permeability, considerable depth, high temperature (150–650 °C), and high pressure, the stimulation of HDR is challenging. This research work aims to examine the efficacy of cryogenic fracturing on HDR. We performed fracture toughness and indirect tensile stress (Brazilian tests) on granite specimens with three different initial temperatures before exposure to liquid nitrogen (LN₂). Fracture toughness tests were implemented on semicircular bend (SCB) specimens containing a pure mode-I fracture, and Brazilian tests were performed with discs. The experimental outcomes show that, overall, both critical load in Brazilian tests and the fracture toughness of LN₂-treated specimens of granites both diminished with increasing initial temperature. When the initial temperature exceeded 300 °C (in this instance, 500 °C), the amplitude of thermally induced fractures in granite moderately increased after LN₂ treatment, secondary fractures prolonged, and the plastic characteristics increased. Moreover, permeability measurements indicated amelioration with elevated temperatures and subsequent LN₂ exposure. SEM analysis showed that an increase in initial temperatures along with LN₂ treatment led to further intensified granite microdamage while the quantity and the magnitude of thermal fractures augmented.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213436"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142561144","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}

{"title":"Induced seismicity in the Kiskatinaw area of Northeastern British Columbia, Canada: Empirical investigation of hydraulic diffusivity and induced seismic response of the fractured reservoir","authors":"Ali Mehrabifard ,&nbsp;Steve Rogers ,&nbsp;Ciara Byrne ,&nbsp;Erik Eberhardt","doi":"10.1016/j.geoen.2024.213458","DOIUrl":"10.1016/j.geoen.2024.213458","url":null,"abstract":"<div><div>This empirical study investigates the mechanistic reasoning behind the occurrence of large magnitude fluid-injection-induced seismic events during hydraulic fracturing in the Kiskatinaw area. The data unveiled atypical non-parabolic spatio-temporal distributions of induced seismic event hypocenters—previously unreported in existing literature. These distributions were predominantly associated with larger magnitude events. Distinctly, our research delves into the concept of hydraulic diffusivity within fractured reservoirs, interpreting the observed patterns in these unique spatio-temporal hypocentral growth distributions. The study reveals that in unconventional fractured reservoirs of this region smaller seismic events are linked to active stages via low hydraulic diffusive and highly hydraulically connected, dispersed, fracture network, while larger magnitudes can associate with highly diffusive and concentrated fractured pathways with limited hydraulic connectivity. This was attributed to the contrasting storativity of connected fracture networks impacting fluid pressure propagation pace to hydraulically connected seismogenic faults. Furthermore, the data pointed to an inverse relationship between hydraulic diffusivity and the number of hydraulically connected structures to the active stage, leading to higher pressure build-ups and larger seismic event magnitudes at greater diffusivity levels. This understanding offers insights into the variances in seismic responses across stages and wells. Intriguingly, unlike standard hydraulic fracturing of unconventional reservoir models emphasizing on tensile fracture generation, our findings underscore the significant role of pre-existing natural fractures in inducing shear slip during fluid injection. The seismic energy release to hydraulic energy input ratio observed was considerably higher than in settings with more massive rocks, aligning with results reported for enhanced geothermal operations. Conclusively, fluid injection in certain fractured reservoirs of the KSSMA can lead to significant pressure buildup perturbations, causing larger seismic events, while in others, a multitude of smaller events prevails, highlighting the complex interplay of hydraulic diffusivity, fracture intensity, and connectivity in determining seismic responses.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213458"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573061","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}

{"title":"Improved severe slugging modeling and mapping","authors":"V. Banjara ,&nbsp;E. Pereyra ,&nbsp;C. Avila ,&nbsp;D. Murugavel ,&nbsp;Sarica C","doi":"10.1016/j.geoen.2024.213446","DOIUrl":"10.1016/j.geoen.2024.213446","url":null,"abstract":"<div><div>One of the common flow assurance issues in offshore production facilities is riser-based severe slugging. This phenomenon can also occur in horizontal wells, hindering oil and gas production. Severe slugging is a cyclic process that occurs in the late life of reservoirs when there is not enough energy available from the reservoir to push the liquid out of the riser. It is highly undesirable as it results in large fluctuations in pressure, oil, and gas flow rates at the outlet of the riser. To address this challenge, we propose an improved one-dimensional severe slugging modelthat enhances the blowout step of the slugging cycleand Compared to the existing one-dimensional models. For benchmarking, the performance of this proposed model has been compared with experimental data for lab-scale geometry and with the OLGA simulations for field-scale geometry and higher operating pressures. The results demonstrate moderate errors in predicting slug characteristics, affirming the model's reliability and applicability. Additionally, a severe slugging envelope prediction approach has been proposed utilizing the developed model. The proposed severe slugging envelopes modeling approach can demarcate the severe slugging flow region for a given pipeline riser geometry and predict severe slug characteristics, including slug length and slug time within that severe slug flow region. This work significantly contributes to flow assurance strategies in production, optimizing hydrocarbon extraction processes and minimizing operational disruptions.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213446"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142578879","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}

{"title":"New algorithm of three-phase equilibrium calculations for CO2-hydrocarbon-water systems","authors":"Ruixiao Sun ,&nbsp;Huanquan Pan ,&nbsp;Hamdi Tchelepi","doi":"10.1016/j.geoen.2024.213426","DOIUrl":"10.1016/j.geoen.2024.213426","url":null,"abstract":"<div><div>In this century, global warming caused by the accumulation of atmospheric carbon dioxide has become an essential concern. The industry has two main decarbonization options: CO₂ capture for permanent storage in geological formations and CO₂ utilization for enhancing oil recovery (EOR). Both methods require accurate reservoir simulation to correctly describe the fluids flowing process and design an optimal injection plan. However, existing reservoir simulation practices often neglect the interaction and dissolution of CO₂ and hydrocarbon components in water, leading to inaccurate predictions. Neglecting CO₂ dissolution in water undermines storage estimation for capture and results in unreliable EOR descriptions. Therefore, to address this, our study focuses on developing a reliable and accurate phase equilibrium calculation package for hydrocarbon-CO₂-water three-phase systems, which meets the demanding efficiency and robustness criteria of reservoir simulation. In this paper, we first introduce the methodology of the three-phase equilibrium calculation algorithm, then illustrate the numerical techniques employed to improve computational efficiency and finally demonstrate superior robustness of this algorithm through comprehensive case studies. Our research contributes three key improvements. First, we have increased the reliability of phase behavior descriptions by considering the dissolution of CO₂ and hydrocarbon components in water. Second, we have enhanced the robustness of the three-phase equilibrium calculations algorithm, enabling accurate determination of three-phase statuses and fluid behaviors where standard commercial software may fail. Third, our algorithm exhibits notable efficiency improvements, ensuring its suitability for three-phase compositional simulations. The findings of this research provide valuable insights into the accurate modeling of hydrocarbon-CO₂-water three-phase systems and offer practical solutions for designing effective CO₂ reduction strategies.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213426"},"PeriodicalIF":0.0,"publicationDate":"2024-10-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573062","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}