Petroleum Research最新文献

{"title":"Comparative organic geochemistry of shale deposits of northern Appalachian Basin","authors":"Nandini Kar ,&nbsp;Kathryn Tamulonis ,&nbsp;Richard W. Smith ,&nbsp;Stella C. Woodard ,&nbsp;Mark R. Noll ,&nbsp;Reilly M. Blocho ,&nbsp;Andre Brunette ,&nbsp;William A. Heins","doi":"10.1016/j.ptlrs.2024.09.002","DOIUrl":"10.1016/j.ptlrs.2024.09.002","url":null,"abstract":"<div><div>The organic-rich black shales in the Appalachian basin are a vital producer of natural gas. In this study, we present new multiproxy geochemical data from the Ordovician and Devonian black shales in New York (NY) and Pennsylvania (PA). The samples include outcrop samples collected in NY (Utica Group and Marcellus Formation) and core samples from PA (Marcellus Formation, Skaneateles Formation, and Genesee Group). We combined organic geochemical data (% total organic carbon or %TOC, δ¹³C_org, C/N ratio, and lipid <em>n</em>-alkane distribution) with trace element (TE) data to identify the organic matter (OM) sources and depositional conditions. The TE analysis data shows that water conditions were variable during the deposition of these black shales, fluctuating between oxic and dysoxic conditions with occasional anoxia. There was probably a change from an open water condition (Co∗Mn = 0.2) during the deposition of the Flat Creek Formation to a more restricted exchange later during the deposition of the Indian Castle Formation (Co∗Mn = 2.9) in the Ordovician. Basin circulation likely remained restricted during the deposition of the Devonian black shales (Co∗Mn ranges from 0.4 to 1.3). Based on δ¹³C_org values (−32.9‰ and −29.6‰) that are more depleted than marine OM δ¹³C_org, C/N ratios (11.2 and 9.2) higher than marine OM, and the presence of longer chain <em>n</em>-alkanes in the range of C25 to C33, we suggest that bryophytes were possibly a significant organic source to the Ordovician Utica Group in NY. The kerogen type in Utica Group samples is type III, mostly terrestrial OM. The Devonian NY and PA samples show mostly bimodal distributions. In some samples, a secondary, though sometimes dominant, shorter chain peak in the range of C14 to C20 is present, in addition to the long chain peak. We suggest the bimodal <em>n</em>-alkane distribution signifies a mixed OM source consisting of terrestrial and marine contributions with differing degrees of thermal maturation compared to the samples with a unimodal distribution. Our results suggest that samples from the NY Marcellus Group are composed of type III kerogen, while samples from the PA Marcellus Formation, Skaneateles Formation, and Genesee Group contain both type II and type III kerogens.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 217-233"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314626","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":"Investigation of structural features of asphaltenes used for carbon materials synthesis by arc plasma treatment","authors":"Andrey Grinko ,&nbsp;Evgenia Leushina ,&nbsp;Yuliya Petrova ,&nbsp;Pavel Povalyaev ,&nbsp;Alexander Pak ,&nbsp;Arina Goncharova ,&nbsp;Vasily Kaichev ,&nbsp;Valentina Egorova ,&nbsp;Kirill Cherednichenko ,&nbsp;Dmitry Zelentsov ,&nbsp;Tatiana Cheshkova","doi":"10.1016/j.ptlrs.2024.10.003","DOIUrl":"10.1016/j.ptlrs.2024.10.003","url":null,"abstract":"<div><div>This study presents analysis of asphaltenes isolated from two crude oils: naphthenic-aromatic biodegraded oil and paraffin-naphthenic oil, which have been used as precursors for carbon materials synthesis. The aim of this study is to investigate the interrelationship between the initial structure of asphaltene and the properties of carbon materials. Based on number of spectroscopic and other data, it can be found out that the asphaltenes from napthenic-aromatic biodegraded oil contain less paraffin and more cyclic fragments (aromatic and aliphatic), that are larger and more densely stacked. The asphaltenes of paraffin-naphthenic oil contain a larger number of labile bonds and heteroatoms. Both the asphaltenes contain sulfur enclosed in thiophene and sulfide fragments, nitrogen and oxygen, which are incorporated in different units with different thermal stability. Carbon materials are obtained from both asphaltenes via plasma of an electric arc discharge. The asphaltenes undergo graphitization as a result of plasma treatment, the general trend is an elimination of functional groups and N, S, O. The yields of the carbon materials are almost equal for two studied asphaltenes, giving graphite-like materials as the major product in both cases. The carbon material obtained from the napthenic-aromatic asphaltenes is less thermally stable, the yield of nano-structures and nanofibers are higher compared to the asphaltenes from paraffinic oil, with trace metals remaining during the synthesis process. The carbon material from paraffin-naphthenic oil is amorphous with low heteroatoms content.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 352-369"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314512","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":"Early oil charging from Sinian shales in Ordovician carbonates of the Tabei Uplift, Tarim Basin: Evidence from biomarkers","authors":"Qingxiu Zeng ,&nbsp;Peng Sun ,&nbsp;Xingchao Jiang ,&nbsp;Heng Zhang ,&nbsp;Qifei Fang ,&nbsp;Lei Jiang","doi":"10.1016/j.ptlrs.2024.11.001","DOIUrl":"10.1016/j.ptlrs.2024.11.001","url":null,"abstract":"<div><div>Despite over 40 years of exploration focusing on the deep to ultra-deep Ordovician carbonates as major hydrocarbon targets in the Tarim Basin, the identification of their source rocks remains elusive. Based on biomarkers, carbon and sulfur isotopes of hydrocarbons, the primary source for the Ordovician petroleum system has been attributed mainly to the lower Cambrian shales, although some oils were likely contributed from the Lower Ordovician source rocks. However, the current understanding of the evolution of the Ordovician petroleum system remains rudimentary, largely due to the complex interplay of multi-source (i.e., the widespread Precambrian shales) hydrocarbon inputs, diagenetic alterations, and tectonic processes over geological time. This study systematically investigates the molecular geochemistry of reservoir bitumen within the Ordovician carbonates from Tabei uplift, coupled with bitumen from the Sinian units at the western edge of the Tarim Basin. Our results indicate that the ion chromatography-mass spectrometry spectra and the saturated to aromatic hydrocarbons ratio of Ordovician reservoir bitumen closely resemble those of Sinian bitumen, as well as the published data of Sinian shales. This coupling linkage is revealed by cross-plots and ternary phase diagrams of various biomarker parameters, which can effectively distinguish the Sinian sources from other sources, i.e., the Lower Cambrian and Ordovician, for the Ordovician reservoir bitumen. Specifically, the ∑n-C₂₁^-/∑n-C₂₂⁺, Pr/Ph, G/C₃₁H22S, C₂₃/C₂₁TT ratios are effective indexes to differentiate these source rocks. By compiling the published organic geochemistry data of oils, it appears to infer that approximately 8.1% of the present-day oils produced from the Ordovician carbonates likely contain some proportion of Sinian-sourced oils. The recognition of Sinian sourced oils contributing to the paleo- and present-day Ordovician petroleum system offers valuable insights for the exploration of deep-ultra deep carbonates in the Tarim Basin, emphasizing the need to consider Precambrian shales as a significant hydrocarbon source.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 234-246"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314627","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":"High-resolution sequence stratigraphy of the Ponta do Mel Formation, Potiguar Basin, Brazil: Insights into shallow-marine carbonate reservoir zonation and characterisation","authors":"A.J.C. Magalhães ,&nbsp;A.H. Melo ,&nbsp;G.J.S. Terra ,&nbsp;D.G.C. Fragoso ,&nbsp;U.M. Soares ,&nbsp;F.P. Lima-Filho","doi":"10.1016/j.ptlrs.2024.12.002","DOIUrl":"10.1016/j.ptlrs.2024.12.002","url":null,"abstract":"<div><div>This comprehensive study establishes a novel high-resolution sequence stratigraphic framework for a shallow, warm, land-tied carbonate-rimmed shelf represented by the Ponta do Mel Formation. Integration of cores and cuttings with seismic and well-log data provides the detailed subsurface stratigraphic framework encompassing two fourth-order genetic sequences. The high-resolution approach unveiled the step-by-step depositional and diagenetic evolution of the Ponta do Mel Formation at the fourth-order systems tracts scale and established the reservoir zonation. In each zone, the lateral contact between high-energy outer shelf and shelf rim potential reservoirs and low-energy inner shelf deposits constitutes critical reservoir heterogeneities that may affect production planning and development projects. Moreover, the reservoir scale enabled discussion on the controls on deposition, high-resolution sequence architecture, diagenesis, and insight into the zonation and characterisation of similar oil and gas reservoirs worldwide.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 304-319"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314641","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":"Gas enhanced oil recovery methods for offshore oilfields: Features, implementation, operational status","authors":"Oleg V. Anikin,&nbsp;Vadim K. Derevyanko,&nbsp;Alexander V. Bolotov,&nbsp;Ilgiz F. Minkhanov,&nbsp;Mikhail A. Varfolomeev,&nbsp;Emilia A. Konstantinovich,&nbsp;Valeria A. Kadysheva","doi":"10.1016/j.ptlrs.2024.12.003","DOIUrl":"10.1016/j.ptlrs.2024.12.003","url":null,"abstract":"<div><div>Nowadays, enhanced oil recovery (EOR) methods have been evaluated both for onshore and offshore oilfields. However, the conditions for using EOR methods in offshore fields are more complex due to the unique features of the infrastructure, transportation facilities and geological conditions. The experience gained from offshore gas EOR (gEOR) pilot projects has shown effective methods for increasing oil production at a later stage of field development. The technical knowledge base gained has been analyzed in this paper, which includes an analysis of the advantages and disadvantages of offshore projects and operational experience with gas and water-gas flooding in offshore environments. A history of implemented EOR projects in offshore oil fields from 1970 to the present and an evaluation of the application of different injection methods with hydrocarbon gas, CO₂ and nitrogen is presented sequentially.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 404-415"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314515","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 role of hydrocyclone and induced gas flotation technologies in offshore produced water deoiling advancements","authors":"Sandro Duarte César ,&nbsp;Debbie De Jager ,&nbsp;Mahomet Njoya","doi":"10.1016/j.ptlrs.2024.10.002","DOIUrl":"10.1016/j.ptlrs.2024.10.002","url":null,"abstract":"<div><div>Produced water, a byproduct of oil and gas extraction, presents significant environmental challenges if not properly treated. This review focuses on advancements in two primary offshore deoiling technologies, namely: induced gas flotation and hydrocyclones, tracing their evolution from the 1940s to the present. The study provides a detailed comparison of these technologies in terms of efficiency, energy consumption, and waste generation, offering both qualitative and quantitative assessments. Particular attention is given to the integration of hydrocyclone-induced gas flotation (HIGF) systems, which enhance oil removal efficiency while reducing energy consumption, making them an important solution in offshore produced water management. Additionally, the review identifies specific design improvements in flotation units, such as multistage configurations, and explores the role of operational control in optimizing hydrocyclone performance. Global variations in produced water discharge standards are examined, emphasising the need for stricter environmental regulations. In addition, this study highlights the combined use of hydrocyclone and flotation technologies as a comprehensive approach for addressing both environmental and operational challenges in offshore produced water treatment.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 342-351"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314511","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":"Organic geochemical aspects of aliphatic hydrocarbon fractions for determining coal bed methane exploration strategies of Sawahlunto and Sangatta coals","authors":"Muhamad Nur Khozin,&nbsp;Yulfi Zetra,&nbsp;R.Y. Perry Burhan","doi":"10.1016/j.ptlrs.2025.01.002","DOIUrl":"10.1016/j.ptlrs.2025.01.002","url":null,"abstract":"<div><div>Sawahlunto (SL-02) and Sangatta (KD-04) coals were analyzed for the presence of aliphatic hydrocarbon fraction biomarkers to assess their organic geochemistry and its implications for selecting exploration strategies for coal bed methane (CBM). Structural identification using the gas chromatography–mass spectrometry (GC–MS) method revealed the distribution of n-alkanes, isoprenoids, sesquiterpenoids, and triterpenoids. The organic matter in both coal samples originated from higher terrigenous plants, as indicated by the dominance of long-chain n-alkanes, carbon preference index (CPI) values greater than 1, low vs. high carbon preference index (LHCPI) values less than 1, terrigenous/aquatic ratio (TAR) values over 5, and the dominance of 8β(H)-homodrimane over 8β(H)-drimane. An oxic depositional environment is suggested by a Pr/Ph ratio greater than 1, the presence of hopanes (C31 and C32), and the low abundance of 8β(H)-drimane in both samples. CPI values greater than 1, OEP values greater than 1, LHCPI values less than 1, the abundance of 17α(H),21β(H)-homohopane (22S) compared with that of 17α(H),21β(H)-homohopane (22R), and the presence of several unsaturated biomarkers in the KD-04 sample, such as olean-12-ene, olean-18-ene, and neohop-13(18)-ene, indicate that the coal is relatively immature. A cross plot of the Pr/n-C17 ratio against the Ph/n-C18 ratio in the Hunt diagram classifies the sample as humic coal derived from higher terrigenous plants, deposited in an oxic environment, and as a type III kerogen with gas-generating potential in both the SL-02 and KD-04 coals. These biomarker data and parameters are highly relevant for methane gas miners in SL-02 coal from the Sawahlunto coal mine, West Sumatra, and KD-04 coal from the Sangatta coal mine, East Kalimantan. The CBM is estimated to have a biogenic origin.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 320-330"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314642","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":"Innovative treatment of toxic oily petroleum wastewater with magnetic sludge under UVA light","authors":"Saeedeh Rastgar ,&nbsp;Habibollah Younesi ,&nbsp;Hassan Rezeai ,&nbsp;Hajar Abyar","doi":"10.1016/j.ptlrs.2024.11.005","DOIUrl":"10.1016/j.ptlrs.2024.11.005","url":null,"abstract":"&lt;div&gt;&lt;div&gt;The primary objective of the present study is to address the critical issue of managing the large volumes of toxic oil sludge and oil waste generated in various industrial processes. This environmental challenge poses significant risks to ecosystems and human health, necessitating effective remediation strategies. In this research, we make a pioneering attempt to synthesize a novel photocatalyst, specifically Char/Fe&lt;sub&gt;3&lt;/sub&gt;O&lt;sub&gt;4&lt;/sub&gt;/TiO&lt;sub&gt;2&lt;/sub&gt;-based magnetic waxy diesel sludge, aimed at reducing the complex and hazardous compounds present in toxic oily petroleum wastewater when exposed to ultraviolet light. The synthesis of the Char/Fe&lt;sub&gt;3&lt;/sub&gt;O&lt;sub&gt;4&lt;/sub&gt;/TiO&lt;sub&gt;2&lt;/sub&gt; photocatalyst involved an innovative approach where titanium dioxide (TiO&lt;sub&gt;2&lt;/sub&gt;) was meticulously coated onto specially prepared synthetic magnetic activated carbon. A comprehensive array of analytical techniques was employed to substantiate the successful synthesis of the photocatalyst. These analyses included Fourier-transform infrared spectroscopy, high-resolution transmission electron microscopy, energy-dispersive X-ray spectroscopy, X-ray diffraction, Brunauer–Emmett–Teller surface area analysis, thermogravimetric analysis combined with differential thermogravimetry, CHNOS analysis, X-ray fluorescence, Raman spectroscopy, diffuse reflectance spectroscopy, and vibrating sample magnetometer techniques. The utilization of these diverse analytical methods provides robust evidence of the structural and functional integrity of the synthesized photocatalyst. The experimental work was conducted in a controlled batch system to evaluate the effectiveness of the photocatalyst under varying conditions. The results obtained from the analyses confirmed the successful incorporation of iron and titanium dioxide within the synthesized magnetic char, thereby validating the synthesis of the photocatalyst. To further optimize the wastewater treatment process, Response Surface Methodology was employed to systematically investigate the influence of various operational parameters. The optimal conditions for the treatment of toxic oily petroleum wastewater were determined to be at a pH of 6.5, with a photocatalyst dosage of 300 mg, a temperature of 35 °C, and an exposure time of 35 min under UVA&lt;sub&gt;6W&lt;/sub&gt; irradiation. Under these ideal conditions, the photocatalytic system demonstrated remarkable efficacy in removing hazardous compounds, achieving removal rates of 98.136% for Chemical Oxygen Demand, 95.194% for Biochemical Oxygen Demand, 92.66% for Total Kjeldahl Nitrogen, 95.99% for Total Dissolved Solids, and 91.99% for Total Suspended Solids. Kinetic and isotherm studies further elucidated the behavior of the photocatalytic process, revealing that the removal of toxic oily wastewater with Char/Fe&lt;sub&gt;3&lt;/sub&gt;O&lt;sub&gt;4&lt;/sub&gt;/TiO&lt;sub&gt;2&lt;/sub&gt; adhered closely to pseudo-first-order kinetic models, as well as the Freundlich and Henderson isotherm models. The negative","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 383-403"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314514","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":"Integrated geological study for reservoir modeling and characterization of the Shurijeh gas bearing sandstones in one of the Northeast Iran gas fields","authors":"Milad Moradi ,&nbsp;Ali Kadkhodaie","doi":"10.1016/j.ptlrs.2024.11.003","DOIUrl":"10.1016/j.ptlrs.2024.11.003","url":null,"abstract":"<div><div>The sandstones deposited in the sequence of Shurijeh Formation comprise a giant gas reservoir in the Northeast of Iran. Five primary facies (petrofacies) were identified in the deposits of Shurijeh Formation such that the entire sedimentary sequence was divided into eight zones. Diagenetic processes have affected the pore properties of sandstone (zone D2). In this research, the petrophysical parameters (porosity and water saturation) and lithology were gamma-ray in the correlation with the petrofacies and core data. The areas with good reservoir properties for each zone and the total reservoir volume were simulated by exerting an appropriate threshold cutoff limit for the reservoir parameter (porosity and water saturation) and shale volume. For determine the economic hydrocarbon volume of the field, the uncertainty analysis in volumetric calculations was carried out utilizing the Monte Carlo method, with the production of Case50, gas-in-place was calculated as 28 × 10⁶ cubic meters. The sensitivity analysis was conducted to determine the impact of each parameter on gas-in-place. Based on the results of this study, the sedimentary facies and diagenesis processes directly affect the in gas-in-place the reservoir. According to the sensitivity analysis, the map of underground lines (UGC) and fluid contact were the most sensitive compared to porosity and water saturation. That the fluid contact is related to the sedimentary facies and diagenetic processes. In fine-grained sedimentary facies, due to the transition zone increase, it is difficult to accurately determine the fluid boundary of the reservoir, while in coarse-grained sediments, which have high permeability, due to the transition zone reduction, the fluid boundary is more accurately determined. Also, diagenetic processes such as cementation, dissolution, and dolomitic processes cause great complexity in determining fluid boundaries. Therefore, comprehensive geological and reservoir studies must be done before any field development work. In this study, the spread of the reservoir zones B and D1, which have the highest volume of in-situ hydrocarbons, with lithofacies that are associated with high-energy environments (mostly sandstone) and have excellent petrophysical parameters in terms of reservoir quality was demonstrated. In accordance with these results, initial depositional processes control the distribution of porosity, water saturation, thickness and extension of prolific areas at the field scale.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 279-294"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314629","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":"Optimization of fracturing parameters for horizontal wells in high-sulfur gas reservoirs considering the effect of sulfur deposition","authors":"Chang Sun ,&nbsp;Zhongjun Zhao ,&nbsp;Jinghong Hu ,&nbsp;Yuan Zhang ,&nbsp;Yidong Cai ,&nbsp;Jun Lu","doi":"10.1016/j.ptlrs.2024.10.001","DOIUrl":"10.1016/j.ptlrs.2024.10.001","url":null,"abstract":"<div><div>During the development of high-sulfur gas reservoirs, the precipitation and deposition of elemental sulfur can lead to a reduction in reservoir porosity and permeability. Previous studies focus on the well production with optimized operational parameters, but the effect of sulfur deposition is not included, which impacts fracturing parameters, well production, and economic evaluation. Therefore, this work proposes a reasonable approach for parameter optimization considering sulfur. The variation of porosity and permeability are first evaluated during sulfur deposition. After that, fracture half-length, fracture spacing, fracture conductivity, and fracture distribution are optimized with orthogonalization factor analysis, and the influence of sulfur deposition on different fracture parameters are detailed analyzed. The results shown that the fracture half-length and fracture conductivity are greatly affected by sulfur deposition. Finally, net profit value is applied to obtain the optimal fracture spacing interval. With economic evaluation, the optimal fracture spacing interval of 125 m–150 m is determined considering the net profit and the payback period. This work provides a useful economic method for fracture parameter optimization high-sulfur gas reservoirs, which benefits for the development and production of gas reservoirs.</div></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":"10 2","pages":"Pages 295-303"},"PeriodicalIF":0.0,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144314640","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}