Petroleum Science最新文献

{"title":"Seepage and blockage characteristics of methane hydrate-bearing porous media under different hydrate distribution conditions","authors":"Guo-Jun Zhao ,&nbsp;Jia-Nan Zheng ,&nbsp;Ming-Jun Yang ,&nbsp;Yong-Chen Song","doi":"10.1016/j.petsci.2025.11.028","DOIUrl":"10.1016/j.petsci.2025.11.028","url":null,"abstract":"<div><div>Blockage commonly occurs in and severally affects natural gas (mainly methane) reservoir exploitation, combustion ice (methane hydrate) exploitation and oil and gas pipeline transportation. The formation of methane hydrates is known as one important cause of blockage, but the effects of hydrate distribution on seepage and blockage are rarely studied in experiments. This study employed different proportions of dry and wet sands to simulate three thickness of hydrate-bearing porous media and obtained a uniform kinetic relationship of hydrate formation (<span><math><mrow><mi>N</mi><mo>=</mo><mi>K</mi><mrow><mo>(</mo><mrow><mn>1</mn><mo>−</mo><mfrac><mn>1</mn><msup><mi>e</mi><mrow><mi>r</mi><mi>t</mi></mrow></msup></mfrac></mrow><mo>)</mo></mrow></mrow></math></span>). Quantitative results indicate that both water and methane seepage can induce hydrate saturation increase in both hydrate-bearing and hydrate-free zones, which gradually causes the blockage of up to 12.5 MPa (at 6.0 MPa backpressure). The hydrate-bearing porous media with a uniform saturation is not easy to cause blockage unless the hydrate saturation is high enough. In addition, based on the hydrate-bearing porous media with different thicknesses, this study successively measured the water phase permeability. In addition, the calculation method for blockage location based on pressure evolution was proposed with an error of less than 8%. These findings can help understand and mitigate issues related to flow blockages during oil and gas exploitation and transportation.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 2263-2274"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855039","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Possible origin of deep hydrocarbons and transformation of complex petroleum systems within the Earth's crust","authors":"Vladimir Kutcherov ,&nbsp;Sergey Marakushev ,&nbsp;Irina Plotnikova ,&nbsp;Kirill Ivanov","doi":"10.1016/j.petsci.2025.11.004","DOIUrl":"10.1016/j.petsci.2025.11.004","url":null,"abstract":"<div><div>We demonstrate that the conditions established in laboratory settings—such as initial reaction products, thermobaric parameters, and redox environments—are indeed analogous to those that may exist in the Earth's upper mantle. The experimental results confirmed that hydrocarbon fluids with diverse compositions can form within the upper mantle. This leads us to propose that these fluids, generated through mantle-magmatic processes, can migrate from sub-crustal zones along deep faults and fractures and be injected under high pressure into the rock, ultimately forming oil and gas deposits. As the ascending fluid cools and the partial pressure of hydrogen decreases, it transforms into liquid oil and subsequently into polymeric insoluble carbonaceous matter (kerogen) within “oil source” rocks. Our findings provide thermodynamic support for the idea that phase transitions involving CO₂, H₂O, oil, and kerogens can occur not only in the kerogen → oil but also in the oil → kerogen direction. The reversibility of phase equilibrium allows us to approach these transitions from an inorganic perspective. Consequently, we can assert that kerogen may be a product of the dehydrogenation of oil and gas. Our experimental results, which investigate the distribution of vanadyl and nickel porphyrin complexes in oils from various productive horizons, support our hypothesis that biomarkers in oils may result from the dissolution and assimilation of dispersed organic matter by ascending, high-temperature hydrocarbon fluids, rather than serving as definitive evidence of a biogenic origin.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 1675-1686"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855045","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Carbon isotopes of asphaltene-occluded hydrocarbons: A proxy for bitumen vein source identification in northwest Sichuan Basin, China","authors":"Peng Fang ,&nbsp;Jia Wu ,&nbsp;Xue-Min Xu ,&nbsp;Bin Shen ,&nbsp;Wei-Lin Sun ,&nbsp;Xiao Jin ,&nbsp;Feng Chen ,&nbsp;Ning-Ning Zhong ,&nbsp;Ming-Hui Zhou","doi":"10.1016/j.petsci.2025.11.024","DOIUrl":"10.1016/j.petsci.2025.11.024","url":null,"abstract":"<div><div>The Lower Cambrian bitumen veins in northwestern Sichuan Basin originated from Precambrian paleo-oil reservoirs, yet the severe alterations of bitumen and high maturity of potential source rocks challenge conventional oil-source correlation. In this study, we focus on analyzing the stability of carbon isotopic compositions in asphaltene-occluded hydrocarbons to reveal their preservation of original organic signatures. Asphaltenes from the solid bitumen were investigated through gold tube closed-system thermal simulation experiments (300–400 °C). Free saturated hydrocarbons in raw samples exhibit ¹³C-enrichment (<em>δ</em>¹³C = −31.3‰) due to biodegradation, while thermal simulation experiments reveal progressive ¹³C-depletion of free saturated hydrocarbons (Δ<em>δ</em>¹³C = −4.7‰) caused by kinetic isotope effects during thermal cracking. In contrast, asphaltene-occluded saturated hydrocarbons maintain exceptional <em>δ</em>¹³C stability (−28.5‰ ± 0.2‰) across the same stages, demonstrating complete protection by macromolecular shielding, and adsorbed hydrocarbons display intermediate behavior with moderate <em>δ</em>¹³C shifts, indicating partial shielding at asphaltene surfaces. Biomarker distributions (C₂₇-dominant steranes, <em>n</em>-alkane bimodality, and <em>n</em>-alk-(1)-enes) in occluded hydrocarbons probably preserve original signatures unaffected by secondary alterations. The combined <em>δ</em>¹³C signature (within the −26‰ to −31‰ range characteristic of shallow-water Doushantuo Formation) and biomarker evidence (consistent with Precambrian eukaryotic algal contribution) in occluded hydrocarbons conclusively identify the Ediacaran Doushantuo Formation as the bitumen source. These results demonstrate that asphaltene nanoaggregates effectively shield occluded components from secondary alterations and thermal maturation to a certain extent, providing reliable proxies for Precambrian oil-source correlation in altered reservoirs.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 1636-1649"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855170","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Mechanical characteristic and damage mechanism of carbon/glass composites in offshore oil exploration","authors":"Yan-Wen Zhang ,&nbsp;Yu-Jing Chen ,&nbsp;Jia-Qi Che ,&nbsp;Yu-Feng Jiang ,&nbsp;Wen-Cheng Liu ,&nbsp;Xin-Fu Liu","doi":"10.1016/j.petsci.2025.11.029","DOIUrl":"10.1016/j.petsci.2025.11.029","url":null,"abstract":"<div><div>Carbon/glass hybrid rods exhibit superior tensile strength, low weight, and exceptional corrosion resistance. However, rod splitting presents a considerable challenge to their practical applications, impeding widespread acceptance. A strength prediction model for carbon/glass hybrid rods was created utilizing a multi-mode damage constitutive material model. Tensile experiments were conducted to validate the simulation model, elucidating stress distribution patterns and creating progressive damage evolution laws to clarify failure causes, thus offering theoretical support for the construction of high-strength rods. The results indicated that: (1) Experimental data indicated an average tensile load of 452.4 kN, with failure resulting from brittle fracture and interface debonding; (2) The simulated ultimate tensile load was 439.2 kN, deviating by 3% from experimental values within acceptable engineering accuracy limits; (3) As displacement increased from 0.3 mm to 0.7 mm, von Mises stresses in the coating layer, −40° winding layer, 40° winding layer, and core layer rose from 96.4, 62.2, 43.6, and 199.2 MPa to 229.6, 141.6, 111.1, and 472.4 MPa, respectively; (4) The primary forms of damage were interface debonding, matrix cracking, matrix extrusion, fiber extrusion and fiber fracture. The weak interface strength and asynchronous deformation between the carbon-fiber core layer and the glass-fiber cladding layer facilitated interface slip, leading to the premature failure of the winding layer due to a rapid decline in interface load transfer, ultimately resulting in interlayer splitting failure of the rod.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 2175-2187"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855297","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"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 deep learning framework for full-cycle CCUS-EOR evaluation and optimization under carbon neutrality","authors":"Bin Shen ,&nbsp;Sheng-Lai Yang ,&nbsp;Yi-Qi Zhang ,&nbsp;Xin-Yuan Gao ,&nbsp;Lu-Fei Bi ,&nbsp;Kai Du ,&nbsp;Er-Meng Zhao ,&nbsp;Hong-Bo Zeng","doi":"10.1016/j.petsci.2026.01.028","DOIUrl":"10.1016/j.petsci.2026.01.028","url":null,"abstract":"<div><div>Carbon capture, enhanced oil recovery (EOR)-utilization and storage (CCUS-EOR) is recognized as an effective approach to mitigate greenhouse gas emissions while delivering economic benefits. However, its practical deployment is limited by the absence of advanced deep learning models for petroleum tabular data, the limited adaptability of existing optimization methods, and the lack of comprehensive evaluation for full-cycle CCUS-EOR. Here, we introduce a generalizable framework that integrates mechanism experiments, numerical simulations, and deep learning methods to address these challenges. Three-stage experiments are conducted to clarify microscopic displacement mechanisms and provide key parameters for numerical simulation. Based on field-scale simulations of 20 years of CO₂ water-alternating-gas (WAG) injection followed by 19 years of pure CO₂ storage until 2060, we develop a TabPFN-based meta-learning surrogate model for joint prediction of oil recovery, CO₂ storage, and net present value (NPV), achieving high accuracy (prediction error &lt;2%, <em>R</em>² &gt; 0.97) compared to baseline models. We further apply an improved multi-objective optimization using the Adaptive Crossover and Adaptive Mutation Non-dominated Sorting Genetic Algorithm II (ACAM-NSGA-II) to obtain optimal Pareto solutions. Compared to baseline cases, the proposed framework significantly enhances CCUS-EOR performance, enhancing oil recovery by 27.05% (from 5.95 × 10⁵ t, 35.17% to 1.05 × 10⁶ t, 62.22%), tripling CO₂ storage capacity (from 1.33 × 10⁶ to 4.45 × 10⁶ t), and improving NPV by 68.0% (from $344 million to $578 million). The Pareto front is further divided into three different solution regions, thereby elucidating the underlying physical mechanisms associated with each cluster and providing clear operational insights for target-oriented CO₂-WAG design. This study offers a scalable blueprint framework for large-scale engineering design in petroleum engineering, particularly in tabular prediction and multi-objective optimization contexts.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 2288-2307"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855314","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Deep reparameterization for full waveform inversion: Architecture benchmarking, robust inversion, and multiphysics extension","authors":"Feng Liu ,&nbsp;Ya-Xing Li ,&nbsp;Rui Su ,&nbsp;Jian-Ping Huang ,&nbsp;Lei Bai","doi":"10.1016/j.petsci.2025.12.027","DOIUrl":"10.1016/j.petsci.2025.12.027","url":null,"abstract":"<div><div>Full waveform inversion (FWI) is a high-resolution subsurface imaging technique, but its effectiveness is limited by challenges such as noise contamination, sparse acquisition, and artifacts from multiparameter coupling. To address these limitations, this study develops a deep reparameterized FWI (DR-FWI) framework, in which subsurface parameters are represented by a deep neural network. Instead of directly optimizing the parameters, DR-FWI optimizes the network weights to reconstruct them, thereby embedding network priors and facilitating optimization. To provide guidelines for the design and usage of DR-FWI, we benchmark two initial model embedding strategies: one involves pretraining the network to generate predefined initial models (pretraining-based), and the other directly adds the network outputs to the initial models, along with three representative architectures (UNet, CNN, MLP). Extensive ablation experiments show that combining CNN with pretraining-based initialization significantly enhances inversion accuracy, offering valuable insights into network design. To further understand the mechanism of DR-FWI, spectral bias analysis reveals that the network first captures low-wavenumber features and progressively reconstructs high-wavenumber details. This learning pattern supports adaptive multi-scale inversion and provides a physically interpretable view of the inversion process. Notably, the robustness of DR-FWI is validated under various noise levels and sparse acquisition scenarios, where its strong performance with limited shots and receivers demonstrates reduced reliance on dense observational data. Additionally, a “backbone-branch” structure is proposed to extend DR-FWI to multiparameter inversion, and its efficacy in mitigating cross-parameter interference is validated on a synthetic anomaly model and the Marmousi2 model. These results suggest a promising direction for joint inversion involving multiple parameters or multiphysics.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 1890-1907"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855373","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Biomass-derived amphiphilic nitrogen-doped carbon dots: Molecular design, interfacial regulation, and enhanced oil recovery performance","authors":"Yu Wu ,&nbsp;Yan-Cheng Zheng ,&nbsp;Jian Mu ,&nbsp;Fu-Chang You ,&nbsp;Zheng-Yu Li","doi":"10.1016/j.petsci.2025.12.011","DOIUrl":"10.1016/j.petsci.2025.12.011","url":null,"abstract":"<div><div>In response to the overlooked influence of precursor molecular structure on interfacial performance in the application of amphiphilic carbon dots (CDs) for enhanced oil recovery (EOR), this study synthesized nitrogen-doped CDs (NCDs, FG, and TA series) using biomass-derived precursors via carbonization, amidation, quaternization, and alkylation. The relationships between precursor structure, surface functionality, interfacial behavior, and oil displacement performance were systematically investigated. TA-derived NCDs exhibited higher surface polarity and amphiphilicity due to abundant carboxyl groups, while increasing alkyl chain length enhanced hydrophobicity and suppressed surface defects. TA-NCDs-L16 showed the best interfacial properties, with a critical micelle concentration (CMC) of 0.104 g/L, <em>γ</em>_CMC of 24.71 mN/m, and zeta potential of +67.80 mV. Under NaCl concentrations ranging from 0 to 12 wt%, the oil–water interfacial tension decreased to a minimum of 0.00151 mN/m, and the contact angle dropped to 16.3°, indicating excellent salt tolerance and wettability reversal capability. In low-permeability core flooding tests, TA-NCDs-L16 achieved a significantly enhanced final oil recovery of 60.42%, with a 27.26% increase in recovery and a 38.71% reduction in injection pressure. The improved EOR performance was attributed to ultra-low interfacial tension, the formation of high-density polar adsorption layers, and nanoscale size effects that enabled efficient pore-throat penetration and fluid redistribution, thereby facilitating the detachment and mobilization of residual oil. In high-salinity formation water containing Ca²⁺/Mg²⁺ and under elevated temperatures (50–90 °C), further evaluation confirmed that the amphiphilic NCDs maintained strong interfacial activity and sustained wettability reversal. TA-NCDs-L16 retained an ultra-low interfacial tension (∼0.002 mN/m) and stable wettability regulation even after 240 h of thermal aging at 80 °C, while core flooding still exhibited significant reductions in injection pressure and enhancements in oil recovery. This study clarifies the correlation among precursor structure, functional group configuration, interfacial behavior, and oil displacement efficiency, providing theoretical guidance and material design concepts for the development of carbon-based amphiphilic nanofluids in low-permeability reservoir applications.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 2046-2065"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147331670","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A high-temperature and high-strength polymer gel for plugging in fractured formations","authors":"Yuan Liu ,&nbsp;Ying-Rui Bai ,&nbsp;Jin-Sheng Sun ,&nbsp;Kai-He Lv ,&nbsp;Jing-Bin Yang ,&nbsp;Ke-Qing Yang ,&nbsp;You-Ming Lang","doi":"10.1016/j.petsci.2026.01.001","DOIUrl":"10.1016/j.petsci.2026.01.001","url":null,"abstract":"<div><div>Lost circulation, the significant penetration of drilling fluid into formations during drilling, leads to excessive fluid consumption, non-productive time, and potential well control incidents. This study developed a tunable polymer gel system for plugging lost circulation zones of various scales. Its mechanical properties can be controlled by adjusting the concentration, temperature, gelling time, and aging time. At 120 °C and 10 h gelling time, increasing concentration from 12% to 20% steadily enhanced mechanical properties: storage modulus rose from 750 to 3171 Pa, and tensile stress increased from 20.03 to 67.8 kPa. However, under different temperature and time regimes, the mechanical properties of polymer gels first strengthened and then weakened or showed a trend of strengthening, weakening, and then strengthening again. For example, under gelling temperature 120 °C and 14% concentration, when the gelling time was increased from 4 to 10 h, the tensile stress of polymer gel increased from 4.103 to 30.07 kPa, but when the gelling time was further extended from 10 to 12 h, the tensile stress was reduced from 30.07 to 11.33 kPa. With further extension of time to 14 h, the tensile stress increased again to 43.91 kPa. Comprehensive microstructural analysis revealed how these factors influence gel properties. Subsequently, the simulated plugging experiments of fractures and sand-filled pipes were conducted using the polymer gel with a concentration of 14% and a temperature of 140 °C for 8 h, and the plugging strength was 5.8 MPa for the parallel fracture of 5 mm, and 10.06 MPa for the sand-filled pipe with a 3 mm fracture and an inner diameter of 3 cm in the outlet pipe, which indicated that the polymer gel system exhibited strong pressure-bearing plugging ability for both the fracture and the fracture/vuggy. The proposed polymer gel was applied in the field of HD29-H8 well in the Tarim Basin of Xinjiang, China, and successfully plugged the loss formation above 5000 m, which demonstrated that it can effectively plug high-temperature and high-pressure reservoirs.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 1955-1969"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855371","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CT investigation on oilwell cement deterioration caused by H2S along a leaking channel under high temperature: Insights for geothermal applications","authors":"Yue Yin ,&nbsp;Li-Wei Zhang ,&nbsp;Kai-Yuan Mei ,&nbsp;Xiao-Wei Cheng ,&nbsp;Man-Guang Gan ,&nbsp;Yan Wang ,&nbsp;Chun-Mei Zhang","doi":"10.1016/j.petsci.2025.12.001","DOIUrl":"10.1016/j.petsci.2025.12.001","url":null,"abstract":"<div><div>The alteration of oilwell cement due to H₂S poses a significant threat to wellbore structural integrity in geothermal environments. However, laboratory studies on the cement deterioration process caused by H₂S flow along a leaking channel under high-temperature conditions remain scarce. In this study, computed tomography (CT) scanning was utilized to assess the morphological changes and alteration patterns of oilwell cement caused by H₂S flow in multiple dimensions. Additionally, scanning electron microscopy (SEM) coupled with energy-dispersive X-ray spectroscopy (EDS) and Fourier transform infrared spectroscopy (FTIR) were applied to elucidate the microscale mechanisms responsible for the H₂S-driven alteration. The results show that: H₂S flow along the cement channel results in increased cement matrix porosity and formation of large pores, which are especially evident in regions adjacent to the channel. Chemical etching and secondary crystal growth contribute to the expansion of channel dimension and roughening of the channel wall. Consequently, the permeability of the cement matrix exhibited a marked increase of 45% over a period of 14 days. At the microstructural level, compared to unaltered oilwell cement, which exhibits a homogeneous texture and fine particle composition, exposure to H₂S leads to the formation of a heterogeneous and fractured structure within the cement. As a result of sulfidation reactions, a surface layer approximately 1 mm in thickness forms on the cement, which is depleted in calcium and enriched in silicon. The identification of metallic sulfides elucidated the chemical mechanisms responsible for the deterioration of cement properties. In summary, the flow of H₂S through the channel within the cement causes significant alteration of the cement structure compared to other alteration modes.</div></div>","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Pages 2235-2247"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855172","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"OFC","authors":"","doi":"10.1016/S1995-8226(26)00212-8","DOIUrl":"10.1016/S1995-8226(26)00212-8","url":null,"abstract":"","PeriodicalId":19938,"journal":{"name":"Petroleum Science","volume":"23 4","pages":"Page OFC"},"PeriodicalIF":6.1,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147855155","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}