Natural Gas Industry B最新文献

{"title":"Geochemistry and the genesis of natural gases in the deep reservoirs of the Bozhong Depression, Bohai Bay Basin, China","authors":"Feilong Wang ,&nbsp;Guomin Tang ,&nbsp;Zilong Zhao ,&nbsp;Rongtao Chen ,&nbsp;Ge Yan","doi":"10.1016/j.ngib.2024.11.002","DOIUrl":"10.1016/j.ngib.2024.11.002","url":null,"abstract":"<div><div>A large gas field with reserves of nearly 200 billion m³—BZ19-6—was discovered in the Bozhong Depression in the Bohai Bay Basin in 2018. There is a considerable difference between the amount of natural gas that would traditionally be expected to be generated by the thermal degradation of low-mature kerogens and the resources that have been confirmed by exploration. Therefore, the geochemical characteristics and the genesis of gas have become crucial aspects of investigating deep natural gas in the Bozhong Depression. The deep gas in the depression is predominantly methane. Its dry coefficient (C₁/C_1-5) ranges from 0.73 to 0.94, which is generally characterized as wet gas. The main non-hydrocarbon gases are CO₂ (1.26 %–52.00 %) and N₂ (0.1 %–0.74 %), with traces of H₂S (10.44 × 10⁻⁶–36.63 × 10⁻⁶ ppm). The natural gases are thermogenic oil-type gases from the Shahejie and Dongying Formations. The deep natural gas in the Bozhong Depression is mainly derived from kerogen degradation, with contributions from oil cracking gas in the BZ1/19 and BZ2/3 structures. Complex carbon isotopic reversals are caused by the filling and mixing of natural gas with different maturities from the same source, evaporative fractionation due to the filling of late-stage high-mature natural gas, and Rayleigh fractionation under deep exogenous temperatures in the presence of transition metals. Combining the analysis of the fluid properties of natural gas, the evaluation of the performance of the migration system, and the understanding of the accumulation background indicates a high possibility that the gas was supplied from multiple hydrocarbon sources over long distances in the late stage. Thus, advantageous traps with high temperatures, close proximity to source kitchens, and favorable migration conditions are the preferred targets for future natural gas exploration in the Bozhong Depression.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 645-660"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217210","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Gas generation potential of Oligocene source rocks in Yinggehai Basin","authors":"Xiaoxiao Guo,&nbsp;Lin Hu,&nbsp;Yangyu Wu,&nbsp;Xiaofeng Xiong,&nbsp;Hanwen Yu,&nbsp;Lei Xia","doi":"10.1016/j.ngib.2024.11.006","DOIUrl":"10.1016/j.ngib.2024.11.006","url":null,"abstract":"<div><div>For many years, natural gas exploration in Yinggehai Basin has mainly focused on Miocene source rocks, and several exploration successes and insights have been achieved. However, limited research on Oligocene source rocks severely hinders natural gas exploration in the slope zone of the basin. Based on a detailed analysis of the geochemical characteristics of natural gas and source rocks, combined with regional oil and gas geological conditions, basin modeling was used to evaluate Oligocene oil and gas resource potential in the study area. The results indicate the following. First, mudstone source rocks of fair to excellent level were developed in the Oligocene, and high-quality coal measure source rocks were present in certain localities, all of which were gas-prone source rocks. The quality of the source rocks of Yacheng Formation was slightly better than that of Lingshui Formation. Second, the source rocks of the Oligocene can be divided into two types on the basis of their source compositions. One type was mainly composed of terrestrial higher plants, represented by the source rocks of Well L20-1 in Northern Yinggehai Sag, and the other type was mainly composed of lower aquatic organisms, represented by the source rocks of Well Z11-1 in Yingdong Slope. Third, Oligocene source rocks have great potential, with a natural gas resource more than 1.0 × 10¹² m³. They were mainly distributed in Northern Yinggehai Sag and Yingdong Slope. The maximum gas generation intensity can reach 100 × 10⁸ m³/km². We conclude that Oligocene source rock resources in Yinggehai Basin have great potential and that areas with high gas generation intensities are mainly concentrated in Northern Yinggehai Sag and the southern section of Yingdong Slope, which are the main targets for future natural gas exploration.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 728-738"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217312","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Gas generation and main gas source rocks in Baiyun Sag and the Pearl River Mouth Basin of the northern South China Sea","authors":"Zulie Long ,&nbsp;Guangrong Peng ,&nbsp;Cong Chen ,&nbsp;Xudong Wang ,&nbsp;Yuping Huang ,&nbsp;Chuang Shi","doi":"10.1016/j.ngib.2024.11.003","DOIUrl":"10.1016/j.ngib.2024.11.003","url":null,"abstract":"<div><div>Due to the limited number of exploration wells in Paleogene mudstones, as well as the complex and diverse types of delta, lacustrine, and marine source rocks in locations in the marine–continental transitional zone, there have been few studies of the gas generation mechanism of source rocks in Baiyun Sag. This has resulted in a long-term dispute about the types and stratigraphic sequences of the main gas source rocks. In this study, gas generation simulation experiments were performed using a high-temperature and high-pressure gold tube closed system on various types of source rocks (i.e., semi-deep lacustrine, shallow lacustrine, delta, and marine transgression/marine facies) from three sets of strata from the Wenchang, Enping, and Zhuhai Formations drilled in Baiyun Sag. Then, the hydrocarbon-generation processes and production characteristics of different types of source rocks at different stratigraphic sequences were rebuilt, and the composition and carbon isotope characteristics of the natural gas generated from these source rocks at different evolution stages were identified. Based on established natural gas generation kinetic modeling of virtual well points in different structural parts of Baiyun Sag, and constrained by the present gas reservoir characteristics and accumulation periods, it was demonstrated that the third and fourth members of the Wenchang Formation in the slope–depression area of the main subsag would have been the main gas source kitchens in Baiyun Sag. However, due to the overall high degree of thermal evolution in the depression area, the generation of natural gas with maturity comparable to the present gas reservoirs was too early—that is, before 20 Ma—to be effectively captured.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 661-678"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217211","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Sustainable hydrate inhibition: Pectin and MEG synergy for deep-sea environments","authors":"Ankur Singh ,&nbsp;Shanker Krishna ,&nbsp;Ajay Suri ,&nbsp;Lavish Kumar Singh ,&nbsp;Isaac Wilson","doi":"10.1016/j.ngib.2024.11.001","DOIUrl":"10.1016/j.ngib.2024.11.001","url":null,"abstract":"<div><div>To ensure the continuous operation of the oil and gas industry, it is imperative to maintain an uninterrupted flow of oil and gas through pipelines and pay specific attention to preventing disruptions caused by hydrate blockages. Kinetic hydrate inhibitors (KHIs) have garnered considerable interest due to their capacity for effective hydrate prevention with minimal dosages typically ranging from 0.5 wt% to 2 wt%, guaranteeing both safety and efficiency. While some KHIs, such as amino acids and certain classes of ionic liquids, are known to be biodegradable, it is crucial to explore, develop, and thoroughly evaluate more natural and sustainable alternatives to these KHIs. This study investigated the potential of pectin as a biodegradable HI and examines its performance in synergism with monoethylene glycol (MEG). To assess its inhibitory performance, we conducted measurements of the induction time (<em>IT</em>) and hydrate nucleation temperature (<em>T</em>₀) essential for hydrate formation under different conditions. The experimental outcomes indicated that pectin demonstrated slightly lower performance in comparison with commercial KHIs. However, its performance improved significantly when combined with a concentration of MEG. A blend of 0.25 wt% pectin and 2 wt% MEG offered an <em>IT</em> of 6.53 h, while poly(vinyl pyrrolidone) (PVP) and poly(vinyl caprolactam) (PVCap) at 0.25 wt% provided <em>ITs</em> of 4.9 h and 5.9 h, respectively. <em>IT</em> escalated from 2.13 h at 0 wt% MEG to 7.99 h at a MEG concentration of 5 wt%, while <em>T</em>₀ exhibited a notable decrease from 8.32 °C at 0 wt% MEG to 1.39 °C at 5 wt% MEG. The identified synergy between pectin and MEG in hydrate inhibition suggests substantial potential for advancing deep-sea hydrate risk management strategies in future research.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 739-749"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217311","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Origin and accumulation of natural gas in the Carboniferous carbonate in the buried hill A area, Weixinan Depression, Beibu Gulf Basin","authors":"Yufei Gao,&nbsp;Congkai Niu,&nbsp;Yaqing Wang,&nbsp;Tianyou Zhang,&nbsp;Yixuan Zhang","doi":"10.1016/j.ngib.2024.11.005","DOIUrl":"10.1016/j.ngib.2024.11.005","url":null,"abstract":"<div><div>Buried hills constitute a significant oil and gas exploration area in the Weixinan Depression. The A area is a typical buried hill, and carbonate hills are considered major reservoir reserves with rich resources. Geochemical, core observation, microsection, and drilling data have been extracted to study the tectonic control factor of the carbonate buried hill reservoir from the A area in the Weixinan Depression. The results indicate that the carbonate buried hill in the study area mainly consists of karst reservoirs, which are divided from top to bottom into the epikarst, vertical percolate-corrosion, runoff corrosion, and phreatic corrosion zones. The epikarst zone and runoff corrosion zone exhibit the best reservoir physical properties among all zones. The natural gas in the reservoir producing oil-related gas, staying in mature stage without experiencing secondary modification effects. Through a comparison of carbon isotope and parameters of light hydrocarbon, the natural gases can be deemed to probably be sourced from the oil shale of the middle of the Liushagang Formation in an adjacent depression. The fault was connected the source rocks and reservoirs, which were active during the early Holocene to early Miocene. Meanwhile, the oil shale in the middle Liushagang Formation was in the mature stage, resulting in the expulsion of natural gases. Multistage tectonic uplift has subjected the buried hill to long-term weathering and leaching, leading to the formation of storage space. Additionally, secondary development and optimal fault opening positions provide favorable migration conditions for hydrocarbon to accumulate in buried-hill reservoirs.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 714-727"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217561","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The coupling relationships of the Oligocene fault fan system and their control over natural gas accumulation in the Qiongdongnan Basin","authors":"Qingbo Zeng,&nbsp;Chenyang Feng,&nbsp;Haizhang Yang,&nbsp;Mo Ji,&nbsp;Shuang Song,&nbsp;Shuai Guo,&nbsp;Ying Chen","doi":"10.1016/j.ngib.2024.11.004","DOIUrl":"10.1016/j.ngib.2024.11.004","url":null,"abstract":"&lt;div&gt;&lt;div&gt;Oligocene (fan) delta-associated coal measures and marine source rocks are the main gas-generating source rocks in the Qiongdongnan Basin, and (fan) delta sand bodies are the dominant types of reservoirs. By comprehensively utilizing a large amount of 2D and 3D seismic data and new drilling data, the distribution of (fan) deltas and three types of Oligocene fault fan systems were systematically identified; these are thought to have had joint control over the development of hydrocarbon source rocks and reservoirs. The three types of Oligocene fault fan coupling relationships in the Qiongdongnan Basin were found to be fault bend, fault gully, and fault tip. The fault bend type of (fan) delta developed at the bend of the fault and was distributed in the downthrown block of Fault Nos. 5 and 2. The fault tip type developed where the fault died out toward the source direction and was distributed near the east–west faults on the north and south sides of Baodao and Changchang Sags. The fault gully type developed along the fault trend in the downthrown block and was mainly distributed in areas including the northern part of Ya'nan Sag and the Fault No. 3 downthrown block. The fault bend (fan) delta is surrounded by a relatively closed bay environment, and the terrigenously dominated marine source rocks in the still water bay environment were developed with a high hydrocarbon generation index and high hydrocarbon generation potential. Fault tip and fault gully types of (fan) delta plain facies have a wide distribution of plain subfacies, which is conducive to the development of coal-measure source rocks that have excellent gas potential. During sedimentation of the fault gully and the fault tip delta, the terrain was relatively flat, with sand bodies strongly reworked by hydrodynamic force; the reservoir quality of the sand bodies in the underwater distributary channel and estuary dam are good, and the sand bodies have wide distribution. The sand bodies of the fault bend type of (fan) delta were deposited rapidly near the source kitchen, and the degree of sorting and rounding was poor, which resulted in the poor physical properties of the plain subfacies. In the southern and northern step-fault zones of Baodao Sag in the eastern part of this basin, the fault bend, fault tip, and fault trench (fan) deltas were inherited and further developed, and the source-reservoir configuration conditions were favorable. Exploration deployment was carried out in the Baodao 21 area in the northern step-fault zone and the Yongle 10 area in the southern step-fault zone, where new discoveries in natural gas exploration have been realized. In the eastern part of this basin, the fault bend, fault tip, and fault gully (fan) deltas in the southern and northern fault step zones of Baodao Sag were successively developed, which were beneficial for favorable source–reservoir configuration conditions. The natural gas exploration successes in the Baodao-21 area in the northe","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 679-691"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217212","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Genetic types and accumulation models of natural gas in the Weixinan depression of the Beibu Gulf Basin in the western South China Sea","authors":"Desheng Hu ,&nbsp;Gang Zhou ,&nbsp;Xinde Xu ,&nbsp;Junjun You","doi":"10.1016/j.ngib.2024.11.007","DOIUrl":"10.1016/j.ngib.2024.11.007","url":null,"abstract":"<div><div>Exploration in the Weixinan depression of the Beibu Gulf Basin has long focused on crude oil, with less natural gas exploration, so the genetic types and accumulation characteristics of the natural gas in the depression have not been determined. Therefore, this study explored the geochemical characteristics, origins and sources, filling periods, and migration and accumulation models of natural gas in the Weixinan depression of the Beibu Gulf Basin, based on data on natural gas composition, light hydrocarbon composition, stable carbon isotopes, and fluid inclusions. The results showed that the natural gas in the Weixinan depression is mainly composed of hydrocarbon gases, with methane (CH₄) predominating (62 %–96 %, with an average of 78 %). The percentage of heavy hydrocarbon gases (C_2-5) is high (average 20 %), and the drying coefficient (C₁/C_1-5) is generally less than 0.95, indicative of typical wet gas. The carbon isotope ratios of methane (δ¹³C₁) range from −51.60 ‰ to −34.37 ‰, and the carbon isotope ratios of ethane (δ¹³C₂) range from −36.67 ‰ to −16.53 ‰, respectively. The carbon isotopes of alkane gases generally show a positive sequence distribution, and a degree of carbon isotopic reversal in natural gas occurs in some well areas. It is speculated that the carbon isotope reversal may be related to the mixing of natural gas from multiple sets of source rocks in the same stage or from the same set of source rocks in different stages. The natural gas is mainly oil-type gas, probably originating from the oil shale in the lower sub-member of the second member of the Liushagang Formation (E₂<em>l</em>₂^l), with some contributions from the shale in the upper sub-member of the third member of the Liushagang Formation (E₂<em>l</em>₃^u). The study area has seen multiple periods of oil and gas filling. The area away from the sub-sags experienced a single, early period of natural gas filling associated with mature crude oil generated during the same period. However, in the zone near the sub-sags, there have been multiple relatively long periods of continuous natural gas filling. Two migration and accumulation models are developed: indirect natural gas filling with no contact between the source rocks and the reservoirs in the zone away from the sub-sags, and continuous natural gas filling with the source rocks in direct contact with the reservoirs in the zone near the sub-sags. The results revealed the genetic types and reservoir characteristics of the natural gas in the Weixinan depression, which is crucial for decision-making for the next step of natural gas exploration.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 692-702"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217213","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Geochemical signature and origin of natural gas in the Weixinan Depression, Beibu Gulf Basin, South China Sea","authors":"Jiajun Qu ,&nbsp;Lin Wei ,&nbsp;Chunzhen Li ,&nbsp;Dujie Hou ,&nbsp;Desheng Hu ,&nbsp;Yong Man","doi":"10.1016/j.ngib.2024.11.008","DOIUrl":"10.1016/j.ngib.2024.11.008","url":null,"abstract":"<div><div>The Weixinan Depression is a petroliferous depression in the Beibu Gulf Basin. After years of related research, scholars have gained a certain understanding of the oil accumulation law in the depression. In recent years, some gas reservoirs with thicknesses of 14–84 m have been found in this area, showing good exploration prospects for natural gases. However, there are few studies on the geochemical characteristics and origin of natural gases in the depression, which significantly hinders gas exploration. There are three sets of source rocks in the Liushagang Formation: upper, middle, and lower source rocks (SR1, SR2, and SR3). The crude oils are divided into three groups based on geochemical indicators such as carbon isotope, C₃₀ 4-methylsterane index (4-MSI), and Pr/Ph. Group I oils exhibit relatively low carbon isotope and 4-MSI values, Group II oils exhibit relatively low carbon isotope and moderate 4-MSI values, and Group III oils show relatively heavy carbon isotope values. By comparing the gas components, light hydrocarbons, and carbon isotope characteristics of the Weixinan natural gases, it was found that the gases are generally wet and are oil-type gases, with the main difference being maturity. Based on maturity, the natural gases can be divided into highly mature and mature gases. For oil–source and gas–source correlation, the Group I and II oils are considered to be derived from SR1, and the Group Ⅲ oils and natural gases are considered to be derived from SR3.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 703-713"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217214","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Oil and natural gas geochemistry in offshore China: Advances and challenges","authors":"Dujie Hou ,&nbsp;Xiong Cheng ,&nbsp;Lin Wei ,&nbsp;Yajun Li ,&nbsp;Kaikai Li ,&nbsp;Ziming Zhang ,&nbsp;Haiyue Zhang ,&nbsp;Jiejing Bian ,&nbsp;Yan Li ,&nbsp;Wei Si ,&nbsp;Zhenjie Jia ,&nbsp;Jiahao He ,&nbsp;Qian Huang","doi":"10.1016/j.ngib.2024.11.009","DOIUrl":"10.1016/j.ngib.2024.11.009","url":null,"abstract":"<div><div>For many years, oil and natural gas geochemistry has been key to hydrocarbon exploration and exploitation in offshore China. Onshore oil fields have been thoroughly explored and exploited and have now entered the later stages of development. However, the oil and gas resources in the offshore basin of China are still abundant, and they have been relatively little explored, so they will be the main growth target for oil and gas production in the future. China has made many breakthroughs in offshore oil exploration in recent years. A large condensate field—Bozhong 19-6—has been discovered in the Bozhong Depression. Its main source rock is associated with algal blooming in the third member of the Shahejie Formation. The Baodao 21-1 gas field in the Qiongdongnan Basin shows clear signs of receiving terrestrial organic matter from the Yacheng and Lingshui formations. The first ultra-deep water and ultra-shallow gas, found in the Lingshui 36-1 gas field in the Qiongdongnan Basin, has thermogenetic and biogenetic origins. Well WY-1 in the Weixinan Depression marked the initiation of offshore shale oil exploration. Its sweet interval consists of two stable oil shale beds developed at the base and the top of the second member of the Liushagang Formation. However, samples from offshore exploration are often severely contaminated, and the corresponding data can be seriously distorted, which yields fewer core and more cutting samples. Therefore, it is necessary to thoroughly screen test data and to apply decontamination treatment and data correction to contaminated samples. The success rate of offshore exploration usually relies on the accurate prediction of source kitchens. Reservoir geochemistry thus has great significance for the future, as source input geochemical information can be used to trace materials backwards, and source kitchens can be predicted, when geochemistry is combined with enrichment and development models of source rocks and geophysical data.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 6","pages":"Pages 631-644"},"PeriodicalIF":4.2,"publicationDate":"2024-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143217509","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Types of lithofacies in the Lower Cambrian marine shale of the Northern Guizhou Region and their suitability for shale gas exploration","authors":"Lingyun Zhao ,&nbsp;Peng Xia ,&nbsp;Yong Fu ,&nbsp;Ke Wang ,&nbsp;Yuliang Mou","doi":"10.1016/j.ngib.2024.09.006","DOIUrl":"10.1016/j.ngib.2024.09.006","url":null,"abstract":"<div><div>The lithofacies and thermal maturity of the over-mature Lower Cambrian marine shale in the Northern Guizhou Region, and their impacts on reservoir properties in this shale were analyzed by combining geochemistry, mineralogy, and gas adsorption methods. Ten lithofacies were identified, and the dominant lithofacies in the studied shale are lean-total organic carbon (TOC) argillaceous-rich siliceous shale (LTAS), medium-TOC siliceous shale (MTSS), and rich-TOC siliceous shale (RTSS). Since the gas generation potential of organic matter was weak, meso- and macro-pores were compressed or filled during the thermal evolution stage with a vitrinite reflectance (<em>R</em>_O) range of 3.0%–4.0%. The controlling factors for methane adsorption capacity in the shale samples are significantly influenced by TOC content rather than thermal maturity. Among the RTSS, MTSS, and LTAS samples, RTSS exhibits the highest favorability for preserving hydrocarbon gas, followed by MTSS. The shale types in this study play a significant role in determining the properties of shale reservoirs, serving as an effective parameter for evaluating shale gas development potential. The RTSS and MTSS with a <em>R</em>_O range of 2.0%–3.0% stand out as the most favorable target shale types for shale gas exploration and development.</div></div>","PeriodicalId":37116,"journal":{"name":"Natural Gas Industry B","volume":"11 5","pages":"Pages 469-481"},"PeriodicalIF":4.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142538252","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}