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Geochemical assessment of upper Cretaceous crude oils from the Iranian part of the Persian Gulf Basin:Implications for thermal maturity,potential source rocks,and depositional setting

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Petroleum Research 2023年第4期8卷 455-468页

作者： Faramarz Talaie Ali Kadkhodaie Mehran Arian Mohsen Aleali Department of Earth Sciences Faculty of Converging Science and TechnologiesScience and Research BranchIslamic Azad UniversityTehranIran Earth Sciences Department Faculty of Natural SciencesUniversity of TabrizTabrizIran

The Upper Cretaceous carbonate successions of the Sarvak Formation host giant oil reservoirs in the Persian Gulf.In this research,a total of 28 oil samples from nine oilfields located in the western,central and eastern parts of the Persian Gulf region were studied to determine the genetic relationships of oils,depositional setting of possible source rocks,thermal maturity,and source-rock ages in the Persian Gulf basin.According to the measured geochemical data,the source rocks facies vary from marine carbonates and marl/carbonates in the central and eastern oilfields to shale/carbonates in the western oilfields.The Pr/Ph ratio,steranes and terpanes suggest anoxic to dysoxic conditions of the depositional environments.The depositional environments experienced both low water stratification/low salinity and normal salinity/unstratified conditions.Evaluation of the saturated and aromatic biomarkers shows that all oil samples are mature and most of the source rocks lie within the beginning of the oil-generation window.The thermal maturity of the central oilfields is higher than that of the other samples,and has gone beyond the oil-generation stage.The C2s/C2g steranes ratio suggest that the central oilfelds of the Persian Gulf have Paleozoic and Jurassic source rocks,whereas the Sarvak reservoir in other parts of this region is sourced from Cretaceous carbonate rocks.

关键词： Reservoir geochemistry Biomarkers thermal maturity Redox conditions Sarvak formation

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Geochemical fingerprints and hydrocarbon potential of Paleocene mudrocks in the Tano Basin, Ghana: insights from biomarkers and stable carbon isotopes

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Acta Geochimica 2024年第2期43卷 255-279页

作者： Kojo Amoako Nancy Pearl Osei-Boakye Ningning Zhong N’Guessan Francois De Sales Konan Gordon Foli Prince Opoku Appau Clifford Fenyi Ebenezer Apesegah Research Group for Marine Geochemistry(ICBM-MPI Bridging Group) Institute for Chemistry and Biology of the Marine Environment(ICBM)Carl von Ossietzky University OldenburgAmmerlander Heerstr.26129 OldenburgGermany State Key Laboratory of Petroleum Resources and Prospecting College of GeosciencesChina University of PetroleumBeijing 102249China Department of Geological Engineering Faculty of Civil and Geo-EngineeringKwame Nkrumah University of Science and TechnologyKumasiGhana Ghana National Gas Company 225 Osibisa CloseAirport WestAccraGhana Petroleum Corporation GNPCPMBPetroleum HouseTemaGhana

The Paleocene mudrocks in Ghana’s Tano Basin have received limited attention despite ongoing efforts to explore hydrocarbon resources.A thorough geochemical analysis is imperative to assess these mudrocks’petroleum generation potential and formulate effective exploration strategies.In this study,a comprehensive geochemical analysis was carried out on ten Paleocene rock cuttings extracted from TP-1,a discovery well within the Tano Basin.Various analytical techniques,including total organic carbon(TOC)analysis,Rock–Eval pyrolysis,gas chromatography-mass spectrometry,and isotope ratio-mass spectrometry,were employed to elucidate their hydrocar-bon potential and organic facies.Theﬁndings in this study were subsequently compared to existing geochemical data on Paleocene source rocks in the South Atlantic marginal basins.The results indicated that the Paleocene samples have TOC content ranging from 0.68 to 2.93 wt%.The prevalent kerogen types identiﬁed in these samples were Type Ⅱ and Type Ⅲ.Molecular and isotope data suggest that the organic matter found in the Paleocene mudrocks can be traced back to land plants and lower aquatic organisms.These mudrocks were deposited in a transi-tional environment withﬂuctuating water salinity,charac-terized by sub-oxic redox conditions.maturity indices,both bulk and molecular,indicated a spectrum of maturity levels within the Paleocene mudrocks,spanning from immature to marginally mature,with increasing maturity observed with greater depth.In comparison,the organic composition and depositional environments of Paleocene source rocks in the Tano Basin closely resemble those found in the Niger Delta Basin,Douala,and Kribi-Campo Basins,the Kwanza Formation in Angola,and certain Brazilian marginal basins.However,it is worth noting that Paleocene source rocks in some of the basins,such as the Niger Delta and Brazilian marginal basins,exhibit rela-tively higher thermal maturity levels compared to those observed in the current Paleocene samples from the Tano Basin.In conclusion,the compre

关键词： Paleocene source rocks Source input Depositional environment thermal maturity Hydrocarbon potential Tano Basin West Africa

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thermal maturity evaluation using Raman spectroscopy for oil shale samples of USA:comparisons with vitrinite reflectance and pyrolysis methods

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Petroleum Science 2020年第3期17卷 567-581页

作者： MdGolam Kibria Souvik Das Qin-Hong Hu Asish R.Basu Wen-Xuan Hu Subhadip Mandal Department of Earth and Environmental Sciences The University of Texas at Arlington500 Yates StreetArlingtonTX 76019USA Institute of Energy Sciences Nanjing UniversityNanjing 210093China Integrated Reservoir Solutions Core LaboratoriesHoustonTX 77040USA

thermal maturity is commonly assessed by various geochemical screening methods(e.g.,pyrolysis and organic petrology).In this contribution,we attempt to establish an alternative approach to estimating thermal maturity with Raman spectroscopy,using 24 North American oil shale samples with thermal maturity data generated by vitrinite reflectance(VRo%)and pyrolysis(Tmax)-based maturity calculation(VRe%).The representative shale samples are from the Haynesville(East Texas),Woodford(West Texas),Eagle Ford and Pearsall(South Texas)Formations,as well as Gothic,Mancos,and Niobrara Formation shales(all from Colorado).The Raman spectra of disordered carbonaceous matter(D1 and G bands separation)of these samples were directly obtained from the rock chips without prior sample preparation.Using the Gaussian and Lorentzian distribution approach,thermal maturities from VR were correlated with carbon G and D1.We found that the Raman band separation(RBS)displayed a better correlation for equivalent VRe%than vitrinite reflectance VRo%.The RBS(D1–G)distance versus total organic carbon,free hydrocarbons from thermal extraction(S1),and the remaining hydrocarbon generating potential(S2)indicate that the RBS(D1–G)distance is also related to kerogen type.Data presented here from three methods of maturity determination of shale demonstrate that Raman spectroscopy is a quick and valid approach to thermal maturity assessment.

关键词： US shale Raman spectroscopy Vitrinite reflectance thermal maturity

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In-situ Fluid Phase Variation along the thermal Maturation Gradient in Shale Petroleum Systems and Its Impact on Well Production Performance

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Journal of Earth Science 2023年第4期34卷 985-1001页

作者： Qianyou Wang Wei Yang Yaohua Li Zhenxue Jiang Ming Wen Rusi Zuo Xin Wang Zixin Xue Yaohua Wang State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249China Department of Earth Ocean and Ecological SciencesUniversity of LiverpoolLiverpool L693GPUK Unconventional Oil and Gas Sciences and Technology Institute China University of PetroleumBeijing 102249China Oil and Gas Survey China Geological SurveyBeijing 100083China Now at the Lyell Centre Heriot-Watt UniversityEdinburgh EH144APUK State Key Laboratory of Marine Geology Tongji UniversityShanghai 200092China College of Geosciences China University of PetroleumBeijing 102249China Key Laboratory of Metallogenic Prediction of Nonferrous Metals and Geological Environment Monitoring Central South UniversityChangsha 410083China

In-situ fluid phase behavior is important in determining hydrocarbon contents and the multiphase flow through shale reservoirs.The gas-to-oil ratio(GOR) has been recognized as a critical indicator of fluid types.However,little is known about the impact of fluid phase variation across the thermal maturity on shale oil/gas production(e.g.,estimated ultimate recovery,EUR).According to the specific gravity ratio of oil/gas,the producing GOR was converted and normalized into a mass fraction of gas in total hydrocarbons(MGOR) to compare North American shale oil/gas plays with Chinese shale oil and hybrid gas-condensate plays.A correlation between MGOR,the fluid phases,and production data was established to identify five phase stages of flow.MGORvaries systematically with the different production zones,which shows promise in rapidly indicating the well production performance and high production stages of shale oil/gas plays.The hybrid shale gas condensate index,Tmax,and total gas contents were integrated to present the fluid types and maturity of shale gas-condensates,which indicates fluid phase and production variation across thermal evolution.The results offer a unique perspective on the shale oil reservoir producibility based on the impact of GOR on fluid phases and EUR from the dominant global oil/gas plays.

关键词： shale oil shale gas gas condensate fluid phase thermal maturity sweet spots GOR EUR.

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Pore structure evolution of lacustrine organic-rich shale from the second member of the Kongdian formation in the Cangdong Sag,Bohai Bay Basin,China

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Petroleum Science 2022年第2期19卷 459-471页

作者： Xiao-Ping Liu Ming Guan Zhi-Jun Jin Zhe Cao Jin Lai Lun-Ju Zheng Wen-Qi Li Biao Sun Shan-Yong Chen State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum(Beijing)Beijing102249China College of Geosciences China University of Petroleum(Beijing)Beijing102249China Research Institute of Petroleum Exploration and Development China National Petroleum CorporationBeijing100083China Institute of Energy Peking UniversityBeijing100871China State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development Beijing100083China Sinopec Petroleum Exploration and Production Research Institute Beijing102206China Wuxi Petroleum Geology Institute Research Institute of Petroleum Exploration and DevelopmentSinopecWuxiJiangsu 214126China Petro China Dagang Oil Field Company Tianjin300280China

Pyrolysis experiments were conducted on lacustrine organic-rich shale from Cangdong Sag in Bohai Bay Basin,China,to investigate the impact of hydrocarbon generation on shale pore structure evolution.thermal evolution is found to control the transformation of organic matter,hydrocarbon products characteristics,and pore structure changes.Furthermore,pore volume and specific surface area increase with increasing maturity.In low-mature stage,the retained oil content begins to increase,pore volumes show slight changes,and primary pores are occluded by the generated crude oil of high molecular weight and density.In the oil-window stage,the retained oil content rapidly increases and reaches maximum,and pore volumes gradually increase with increasing thermal maturity.At high mature stage,the retained oil content begins to decrease,and the pore volume increases considerably owing to the expulsion of liquid hydrocarbon.In over mature stage,natural gas content significantly increases and kerogen transforms to asphalt.Numerous organic pores are formed and the pore size gradually increases,resulting from the connection of organic pores caused the increasing thermal stress.This study lays a foundation for understanding variation of hydrocarbon products during the thermal evolution of lacustrine shales and its relationship with the evolution of shale reservoirs.

关键词： Lacustrine shale Pyrolysis thermal maturity Pore structure evolution Hydrocarbon generation evolution

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Impact of Particle Crush-Size and Weight on Rock-Eval S2,S4,and Kinetics of Shales

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Journal of Earth Science 2022年第2期33卷 513-524页

作者： Deependra Pratap Singh David A.Wood Vivek Singh Bodhisatwa Hazra Pradeep K.Singh CSIR-Central Institute of Mining and Fuel Research Barwa Road campusDhanbad 826015India Academy of Scientific and Innovative Research(AcSIR) Ghaziabad 201002India DWA Energy Limited Lincoln LN59JPUnited Kingdom

The Rock-Eval technique in the last few decades has found extensive application for source rock analysis.The impact of shale particle crush-size and sample weight on key Rock-Eval measurements,viz.the S;curve(heavier hydrocarbons released during the non-isothermal pyrolysis-stage)and the S;curve(CO_(2)released from oxidation of organic matter during the oxidation-stage)are investigated in this study.For high and low total organic carbon(TOC)samples of different thermal maturity levels,it is apparent that particle crush-size has a strong influence on the results obtained from RockEval analysis,with the effect being stronger in high-TOC samples.In comparison to the coarser-splits,S;and pyrolyzable carbon(PC)were found to be higher for the finer crush sizes in all the shales studied.The S_(2)CO_(2)oxidation curve shapes of Permian shales show contrasting signatures in comparison to the Paleocene-aged lignitic shale,both from Indian basins.A reduced TOC was observed with rising sample weight for a mature Permian shale from the Jharia basin,while the other shales sampled showed no significant reduction.The results indicate that the S_(2)CO_(2)curve and the S_(2)T_(2),are strongly dependent on the type of organic-matter present and its level of thermal maturity.Sample weight and particle size both influence the S;-curve shapes at different heating rates.With increasing sample weights,an increase in S;-curve magnitude was observed for the shales of diverse maturities.These differences in the S;curve shape lead to substantially different kinetic distributions being fitted to these curves.These findings are considered to have significant implications for the accuracy of reaction kinetics obtained from pyrolysis experiments using different sample characteristics.

关键词： high-TOC shale analysis Rock-Eval pyrolysis total organic carbon sample specifications thermal maturity shale reaction kinetics petroleum geology

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Source rock geochemistry of central and northwestern Niger Delta: Inference from aromatic hydrocarbons content

能源地球科学(英文)

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能源地球科学(英文) 2023年第3期4卷 9-17页

作者： Akinsehinwa Akinlua Olugbemiga Raphael Dada Fuad Oluseyi Usman Solomon Adeniyi Adekola Fossil Fuels and Environmental Geochemistry Department of ChemistryObafemi Awolowo UniversityIle-IfeNigeria Department of Geology Obafemi Awolowo UniversityIle-IfeNigeria

The influence of origin, depositional environment and thermal maturity of organic matter on the occurrence of aromatic hydrocarbons in source rocks from the central and northwestern Niger Delta was investigated. Eighty two source rock samples from four oil wells in the central and northwestern Niger Delta were analyzed for the aromatic hydrocarbon content using gas chromatography-mass spectrometry (GC-MS). The results of analysis of aromatic hydrocarbon fractions of the source rock extracts show the presence of many classes of aromatic hydrocarbons, which include naphthalenes, phenanthrenes, biphenyls, dibenzothiophenes and fluorenes. Trimethylnaphthalene (TMN) is the most abundant among the naphthalenes while dimethylphenanthrene (DMP) is the most abundant among the phenanthrenes. Among the biphenyls, 3-methylbiphenyl (3 MB) is the most abundant while 4-methyldibenzothiophene (4MDBT) is the most abundant among the dibenzothiphenes. Only two fluorenes were detected, and fluorene is more in abundance than 1-methylfluorene (1 MF). Depositional environment indicators of aromatic hydrocarbon organic matter reveal that the organic materials in the source rocks in these wells were deposited in marine-to-swamp depositional environments under reducing to suboxic conditions. thermal maturity indicators calculated from the abundance of the aromatic hydrocarbons indicate that the source rock samples are thermally mature. Most of the source rocks are at the peak of oil window while a few at the early oil window. Source rocks from wells GB, OP and OT in the central Niger Delta are thermally more mature than those from well AW in the northwestern Niger Delta.

关键词： Source rock Aromatic hydrocarbon thermal maturity Depositi onal envir onment Niger Delta

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Geochemical record for the depositional condition and petroleum potential of the Late Cretaceous Mamu Formation in the western flank of Anambra Basin, Nigeria

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Green Energy & Environment 2020年第1期5卷 83-96页

作者： Gbenga O.Ogungbesan Taofik AAdedosu Department of Earth Sciences Ladoke Akintola University of TechnologyP.M.B.4000OgbomosoNigeria Department of Chemistry Ladoke Akintola University of TechnologyP.M.B.4000OgbomosoNigeria

Carbonaceous shale exposures of the Late Cretaceous Mamu Formation along Ifon-Uzebba road in western arm(Benin Flank) of Anambra Basin, southwestern Nigeria, were analyzed for bulk organic geochemical, molecular biological and poly-aromatic hydrocarbon(PAH) compositions to investigate the organic matter source, paleo-depositional condition, thermal maturity and petroleum potential of the unit. The bulk organic geochemistry was determined using Leco and Rock-Eval pyrolysis analyses while the biomarkers and PAH compositions were investigated using gas chromatography-mass spectrometer(GC-MS).The bulk organic geochemical parameters of the shale samples showed total organic carbon(TOC)(1.11-6.03 wt%), S2(0.49-11.73 mg HC/g Rock), HI(38-242 mg HC/g TOC) and Tmax(425-435 C) indicating good to excellent hydrocarbon source-rock. Typical HI-Tmax diagram revealed the shale samples mostly in the gas-prone Type Ⅲ kerogen region with few gas and oil-prone Type Ⅱ-Ⅲ kerogen. The investigated biomarkers(n-alkane, isoprenoid, terpane, hopane, sterane) and PAH(alkylnaphthalene, methylphenanthrene and dibenzothiophene) indicated that the carbonaceous shales contain mix contributions of terrestrial and marine organic matter inputs that were deposited in a deltaic to shallow marine settings and preserved under relatively anoxic to suboxic conditions.thermal maturity parameters computed from Rock-Eval pyrolysis, biomarkers(hopane, sterane) and PAH(alkylnaphthalene, alkylphenanthrene, alkyldibenzothiophene) suggested that these carbonaceous shales in Anambra Basin have entered an early-mature stage for hydrocarbon generation. This is also supported by fluoranthene/pyrene(0.27-1.12), fluoranthene/(fluoranthene + pyrene)(0.21-0.53) ratios and calculated vitrinite reflectance values(0.49-0.63% Ro) indicative that these shales have mostly reached early oil window maturity, thereby having low hydrocarbon source potential.

关键词： Anambra Basin Mamu formation Paleoenvironment Kerogen thermal maturity

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maturity Assessment of the Lower Cambrian and Sinian Shales Using Multiple Technical Approaches

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Journal of Earth Science 2021年第5期32卷 1262-1277页

作者： Wei Yang Sheng He Gangyi Zhai Ze Tao Xiaoqing Yuan Sile Wei Key Laboratory of Tectonics and Petroleum Resources Ministry of EducationChina University of GeosciencesWuhan 430074China Oil&Gas Survey China Geological SurveyBeijing 100083China

The Lower Cambrian Niutitang and Sinian Doushantuo shales are the most important and widespread source rocks and target layers in South China. Reliable data of the thermal maturity of organic matter(OM) is widely used to assess hydrocarbon generation and is a key property used in determining the viability and hydrocarbon potential of these new shales. Nevertheless, traditional thermal maturity indicators are no longer suited to the vitrinite-lack marine shales. This study aims to combine high throughput Raman and infrared spectroscopy analysis to confirm and validate the thermal maturity in comparison with the bitumen reflectance(R_(b)). Raman parameters such as the differences between the positions of the two bands(V_(G)–V_(D)) are strong parameters for calculating the thermal maturity in a large vitrinite reflectance(R_(o)) ranging from 1.60% to 3.80%. The infrared spectroscopy analysis indicates that the aromatic C=C bands and CH_(2)/CH_(3) aliphatic groups both are closely correlated with thermal maturity. The calculated R_(o) results from Raman and infrared spectroscopy are in strong coincidence with the R_(b). The relationships between R_(b) and pore volumes/surface areas(calculated from N_(2) adsorption) indicate that the sample with R_(b) of 3.40% has the lowest pore volumes and surface areas. Focused ion beam scanning electron microscopy(FIB-SEM) observations of OM pores indicate that R_(o) of approximately 3.60% may be an upper limit for OM porosity development. Obviously, kerogen Raman and infrared spectroscopy can indicate methods for reducing the risk in assessing maturity with practical, low-cost accurate results. Exploration of shale gas in the high maturity(>3.40%–3.60%) region carries huge risks.

关键词： thermal maturity marine shale kerogen raman spectroscopy infrared spectroscopy

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Identification of Hydrocarbon Potential of Talhar Shale: Member of Lower Goru Formation Using Well Logs Derived Parameters, Southern Lower Indus Basin, Pakistan

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Journal of Earth Science 2018年第3期29卷 587-593页

作者： Muhsan Ehsan Hanming Gu Malik Muhammad Akhtar Saiq Shakeel Abbasi Zaheen Ullah Institute of Geophysics and Geomatics China University of Geosciences Department of Earth and Environmental Sciences Bahria University Islamabad School of Environmental Studies China University of Geosciences Faculty of Earth Resources China University of Geosciences

Using well logs data only, the evaluation of shale gas hydrocarbon potential of Talhar Shale Member of Lower Goru Formation has been a challenge in Southern Lower Indus Basin in Pakistan. Well logs data analysis is helpful to evaluate the gas potential of source shale rocks. We introduced and applied empirical and graphical method to fulfil this task and derived geochemical parameters from well logs data. The method mentioned is cheap and fast. Talhar Shale has kerogen type Ⅲ and type Ⅱ which are montmorillonite clay and have potential to produce oil and gas. Talhar Shale has better sorption property. Empirical formulas are used to derive parameters, using well logs of porosity, density and uranium. Porosity and volume of kerogen, calculated from density log, give average values of 11.8% and 11.4%. Average value of level of maturity index （LMI） derived from log is 0.54, which indicates that it is at the early stage of maturity. Vitrinite reflectance is between 0.5%-0.55% as calculated by graphical method and empirical formula. Talhar Shale is at onset of oil generation, with main products of oil and gas. It is a good potential source in the study area.

关键词： Talhar Shale kerogen type sorption property thermal maturity vitrinite reflectance（Ro） Southern Lower Indus Basin.

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