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GEOENERGY SCIENCE ANd ENGINEERING 2023年 225卷

作者： Kamalrulzaman, Kamalia Norjannah Shalaby, Mohamed Ragab Islam, Md Aminul Univ Brunei Darussalam Fac Sci Dept Geosci Jalan Tungku Link Gadong 1410 Brunei Tanta Univ Fac Sci Geol Dept Tanta 31527 Egypt

The aim of this study is to perform source rock characterization of the Lower Cretaceous Latrobe Group's for-mations in the Gippsland basin. A total of 138 source rock samples with coal and shale lithologies were selected from three formations represented by Chimaera, Curlip and Kipper Shale formations. The geochemical analyses consisting Rock-Eval pyrolysis, total organic carbon (TOC), vitrinite reflectance (% VR), maceral composition, and biomarkers were used for source rock characterization of the studied formations. It can be interpreted that the formations have poor to very good TOC (average of 2.32 wt %) indicating good organic abundance, while the coal samples from Chimaera Formation have higher organic abundance with excellent TOC (average of 45.25 wt %). These indicate good hydrocarbon generative potential. The formations mostly generate type II/III (mixed) to type III (gas prone) kerogens. Maturity parameters including production index (PI), temperature of maximum pyrolysis (Tmax), % VR and carbon preference index (CPI) indicated that the source rocks are immature to late mature (oil to oil/gas windows). Paleodepositional environment of source rocks is evaluated with biomarker data - normal alkane distribution, pristane/phytane (Pr/Ph) and isoprenoid/normal-alkane ratios. The results show that the source rocks are dominantly terrestrial, deposited in oxic setting. The rock samples did not show any sign of hydrocarbon migration, but experienced biodegradation. However, biomarker analyses were only done on the Chimaera Formation and the results do not represent the whole source rocks in this study. 1d basin modeling was done for Kipper wells. The results show that in Kipper-1, the oil and gas generations started in Kipper Shale at depths 1900 m about 24 Ma, and 2510 m about 15.4 Ma, respectively. In Kipper-2, oil and gas generations started in Chimaera Formation at depths 2540 m about 8 Ma, and 2580 m about 2.5 Ma, respectively. Trans-formation ratio (TR) pl

关键词： Gippsland basin Lower Cretaceous Latrobe group Source rock characterization 1d basin modeling Petroleum system event

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Burial and thermal history simulation of the Abu Rudeis-Sidri oil field, Gulf of Suez-Egypt: A 1d basin modeling study

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JOURNAL OF AFRICAN EARTH SCIENCES 2018年 138卷 86-101页

作者： Awadalla, Ahmed Hegab, Omar A. Ahmed, Mohammed A. Hassan, Saad Schlumberger Co Fluid Anal Real Time Flair Engineer POB 4064 Dhahran Al Khobar Saudi Arabia Mansoura Univ Fac Sci Geol Dept Sedimentol Mansoura 35516 Egypt Mansoura Univ Fac Sci Geol Dept Appl Geophys Mansoura 35516 Egypt North Sinai Petr Co NOSPCO 13 C Ahmed Kamel St Cairo Egypt

An integrated 1d model on seven wells has been performed to simulate the multi-tectonic phases and multiple thermal regimes in the Abu Rudeis-Sidri oilfield. Concordance between measured and calculated present-day temperatures is achieved with present-day heat flows in the range of 42-55 mW/m2. Reconstruction of the thermal and burial histories provides information on the paleotemperature profiles, the timing of thermal activation as well as the effect of the Oligo-Miocene rifting phases and its associated magmatic activity. The burial histories show the pre-rift subsidence was progressive but modest, whereas the syn-rift was more rapid (contemporaneous with the main rifting phases and basin formation). Finally, the early post-rift thermal subsidence was slow to moderate in contrast to the late post-rift thermal subsidence which was moderate to rapid. The simulated paleo heat flow illustrates a steady state for the pre-rift phase and non-steady state (transient) for syn-rift and postrift phases. Three geothermal regimes are recognized, each of which is associated with a specific geological domain. 1) A lower geothermal regime reflects the impact of stable tectonics (pre-rift). 2) The higher temperature distribution reflects the syn-rift high depositional rate as well as the impact of stretching and thinning (rifting phases) of the lithosphere. 3) A local higher geothermal pulse owing to the magmatic activity during the Oligo-Miocene time (ARM-1 and Sidri-7 wells). Paleoheat flow values of 100mW/m2 (Oligo-Miocene rifting phase) increased to 120mW/m2 (Miocene rifting phase) and lesser magnitude of 80mW/m2 (Mio- Pliocene reactivation phase) have been specified. These affected the thermal regime and temperature distribution by causing perturbations in subsurface temperatures. A decline in the background value of 60mW/m2 owing to conductive cooling has been assigned. The blanketing effect caused by low thermal conductivity of the basin-fill sediments has been simulated a

关键词： Burial and thermal history 1d basin modeling Steady and no steady state Oligocene and miocene rifting Gulf of Suez

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A Novel Hybrid Machine Learning Approach and basin modeling for Thermal Maturity Estimation of Source Rocks in Mandawa basin, East Africa

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NATURAL RESOURCES RESEARCH 2024年第5期33卷 2089-2112页

作者： Mkono, Christopher N. Shen, Chuanbo Mulashani, Alvin K. Ngata, Mbega Ramadhani Hussain, Wakeel China Univ Geosci Key Lab Tecton & Petr Resources Minist Educ Wuhan 430074 Peoples R China Mbeya Univ Sci & Technol Coll Engn & Technol Dept Geosci & Min Technol Box 131 Mbeya Tanzania China Univ Geosci Key Lab Theory & Technol Petr Explorat & Dev Hubei Wuhan 430074 Peoples R China China Univ Geosci Sch Geophys & Geomat Hubei Multiscale Image Key Lab Wuhan 430074 Peoples R China

basin modeling and thermal maturity estimation are crucial for understanding sedimentary basin evolution and hydrocarbon potential. Assessing thermal maturity in the oil and gas industry is vital during exploration. With artificial intelligence advancements, more accurate evaluation of hydrocarbon source rocks and efficient thermal maturity estimation are possible. This study employed 1d basin modeling using PetroMod and a novel hybrid group method of data handling (GMdH) neural network optimized by a differential evolution (dE) algorithm to estimate thermal maturity (Tmax) and assess kerogen type in Triassic-Jurassic source rocks of the Mandawa basin, Tanzania. The GMdH-dE addresses the limitations of conventional methods by offering a data-driven approach that reduces computational time, overcomes overfitting, and improves accuracy. The 1d thermal maturity basin modeling suggests that the Mbuo source rocks reached the gas-oil window in late Triassic times and began expulsion in the early Jurassic while located in an immature-to-mature zone. The GMdH-dE model effectively estimated Tmax with high coefficient of determination (R2 = 0.9946), low root mean square error (RMSE = 0.004), and mean absolute error (MAE = 0.006) during training. When tested on unseen data, the GMdH-dE model yielded an R2 of 0.9703, RMSE of 0.017, and MAE of 0.025. Moreover, GMdH-dE reduced the computational time by 94% during training and 87% during testing. The results demonstrated the model's exceptional reliability compared to the benchmark methods such as artificial neural network-particle swarm optimization and principal component analysis coupled with artificial neural network. The GMdH-dE Tmax model offers a unique and independent approach for rapid real-time determination of Tmax values in organic matter, promoting efficient resource assessment in oil and gas exploration.

关键词： Thermal maturity 1d basin modeling Group method of data handling Source rock Well logs differential evolution

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diagenesis and pressure evolution in Ediacaran carbonate rocks in the North Slope (Penglai area) of the central Sichuan basin (SW China)

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MARINE ANd PETROLEUM GEOLOGY 2024年 164卷

作者： Liu, Xiuyan Fan, Junjia Jiang, Hua Pironon, Jacques Lu, Xuesong Ostadhassan, Mehdi Yangtze Univ Sch Geosci Wuhan 430100 Peoples R China Univ Lorraine GeoRessources Lab CNRS F-54506 Vandoeuvre Les Nancy France China Natl Petr Corp Res Inst Petr Explorat & Dev Key Lab Basin Struct & Hydrocarbon Accumulat RIPED Beijing 100083 Peoples R China China Univ Geosci Key Lab Tecton & Petr Resource Educ Minist Wuhan 430074 Peoples R China Univ Kiel Inst Geosci Marine & Land Geomech & Geotecton D-24118 Kiel Germany

The Penglai area is an emerging giant gas field in the Sichuan basin supporting the carbon neutrality goal. To accelerate the exploration, this study combines petrographic observations using optical and cold cathodoluminescence microscopy, fluid inclusion microthermometry, Raman spectroscopy, 1d basin modeling and fluid inclusion PVTX modeling techniques to reveal the paleo-fluid P-T evolution in the second member of the dengying Formation (Ediacaran age). The results firstly showed a diagenetic sequence which includes three phases of dolomite (1-3), bitumen, quartz (core and overgrowth) and fluorite. Then, ten paleo-fluid episodes were identified based on microthermometric histograms of different mineral phases. Finally, by integrating the Raman results, the hydrostatic and lithostatic gradients calculated by the constructed 1d basin model, and the existing equation of states, the homogenization pressure of fluid inclusions from each fluid episode was determined. By assuming the system was saturated by CH4 as suggested by Raman results, the homogenization pressure equals to the trapping pressure. The P-T trajectory indicates that the second member of the dengying Formation experienced two sever pressure accumulation stages. One is between fluid episode #3 and #4 recorded by dolomite 3, due to oil generation, and the other is from fluid episode #5 in dolomite 3 to episode #7 in quartz overgrowth to episode #8 in fluorite due to oil cracking to gas. Also, two pressure releasing periods were recorded by fluid episode #5 in dolomite 3 and #9 and #10 in fluorite, caused by both basin uplifting and fluid pressure reaching the lithostatic pressure. This study provides insights into fluid pressure evolution in deeply buried carbonate reservoirs. The understandings can support further geoenergy utilization and reduce exploration risks.

关键词： Fluid inclusion PVTX modeling diagenesis 1d basin modeling Raman spectroscopy dolomite Penglai area Central Sichuan basin

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Oligocene source-rock characteristics and hydrocarbon generation modeling of the eastern Nile delta, Egypt

GEOENERGY SCIENCE AND ENGINEERING

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GEOENERGY SCIENCE ANd ENGINEERING 2023年 227卷

作者： El-Shafeiy, Moataz Halim, Nada Abdel El -Kammar, Mohamed El-Bakry, Gihan Cairo Univ Fac Sci Geol Dept Giza 12613 Egypt British Petr Co BP New Cairo Egypt

This study investigates Oligocene source rock development in the eastern Nile delta, integrating TOC, Rock-Eval pyrolysis, as well as vitrinite reflectance (Ro%) measurements from over 9 onshore and offshore wells. 1d basin models, constructed for 2 wells onshore and 2 wells offshore, investigate the burial, thermal histories, and the stage and timing of hydrocarbon generation. The present-day data indicate that the Oligocene section encompasses Type III and rarely Type IV kerogen onshore, whereas offshore Type III and Type II-III kerogen dominate. The back-calculated original TOCo and HIo values indicate a significant hydrocarbon generation (i.e. effective to relic source rock) for Rupelian section in Tayifah deep-1x and Satis-1 wells. The different maturity indicators used here show significant differences in some intervals. The variability may be attributed to natural impregnation of migrated hydrocarbon in permeable strata, in-situ expelled hydrocarbons where S2 contamination is rather likely for samples within the oil window, or retarded Ro% and/or Tmax caused by overpressure. Therefore, thermal and generation models are calibrated with measured bottomhole temperatures, which match quite well with & delta;13C values of gases C1-3, and indicate that the onshore Oligocene basal section comes in the early stage of hydrocarbon generation throughout the middle-late Miocene, and was in the main stage of hydrocarbon generation since the early Pliocene. The transformation ratio indicates an in-situ expulsion (25-50%) since the Pleistocene time. Offshore models indicate the basal Oligocene section entered the late phase of hydrocarbon generation during the early to middle-late Miocene, where its transformation ratio exceeds 50%. This indicates the main hydrocarbon expulsion from the late Oligocene to the early-middle Miocene time. Further integrated approaches to the Oligocene geochemical analysis after solvent extraction are vastly required. Higher resolution overpress

关键词： Source-rock evaluation Oligocene Tineh formation 1d basin modeling East Nile delta Egypt

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An integrated geochemical analysis, basin modeling, and palynofacies analysis for characterizing mixed organic-rich carbonate and shale rocks in Mesopotamian basin, Iraq: Insights for multisource rocks evaluation

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JOURNAL OF PETROLEUM SCIENCE ANd ENGINEERING 2022年第0期216卷

作者： Mahdi, Adnan Q. Abdel-Fattah, Mohamed I. Radwan, Ahmed E. Hamdan, Hamdan A. Imam Jaafar Al Sadiq Univ Baghdad Iraq Univ Sharjah Dept Appl Phys & Astron Petr Geosci & Remote Sensing Program 27272 Sharjah U Arab Emirates Jagiellonian Univ Inst Geol Sci Fac Geog & Geol Gronostajowa 3a PL-30387 Krakow Poland

Shales and carbonate-rich sediments are crucial in characterizing the geological history of petroleum as source rocks. This emphasizes the global significance of carbonate source rocks, and it has sparked research interests and exploration of these strata as unconventional resources. This study presents inclusive organic geochemical characteristics, palynofacies analysis, and basin modeling of the carbonate source rocks in the Ajeel oilfield, Mesopotamian basin, Iraq. This study used traditional and advanced geochemical techniques, as well as microscopic examination and basin modeling. A total of 109 core and cutting samples from the Middle Juras-sic-lowermost Early Cretaceous succession were studied via geochemical and palynological methods to evaluate their thermal maturation, depositional conditions, and hydrocarbon (HC) generation potential by combining one-dimensional (1d) modeling of the burial/thermal history and the generation/expulsion timing in the Mes-opotamian basin, Iraq. The results of total organic carbon/Rock-Eval pyrolysis revealed that the Middle Juras-sic-lowermost Early Cretaceous interval predominantly comprised carbonate-rich sediments with Type-II and mixed Type-II/III kerogen. Furthermore, the results showed that these potential source rocks were of fair to excellent quality (oil window) and were deposited mainly in an anoxic marine environment. Geochemical and palynological investigation suggested that the carbonate-rich source rocks were deposited mainly under a distal suboxic-anoxic condition and contained Type-II kerogen (oil prone), except for part of the Chia Gara Formation, which displayed distal dysoxic-oxic shelf depositional conditions. The 1d basin modeling results of the burial/ thermal maturation history and the generation/expulsion timing showed that these sediments reached their peak generation potential (main oil window) during the Early Miocene, and this has continued until the present day. Subsequently, the Middle Jurassic-l

关键词： Geochemical analysis Organic facies analysis distal suboxic -anoxic environment Palynofacies 1d basin modeling Mesopotamian basin

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Characteristics and generation modeling of some source rocks in the South Eastern offshore Mediterranean area, Egypt

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MARINE ANd PETROLEUM GEOLOGY 2021年 123卷 104719-104719页

作者： Hamdy, dina El-Bakry, Gihan El Habaak, Galal H. El-Shafeiy, Moataz Assiut Univ Geol Dept Fac Sci Assiut Egypt British Petr Co PLC Cairo Egypt Cairo Univ Geol Dept Fac Sci Giza 12613 Egypt

The offshore North Sinai area contains attractive approaches to be investigated by means of hydrocarbon potential. The present work aims at evaluating three source rock units;the Upper Jurassic, the Lower Cretaceous, and the Upper Oligocene that have a varying lithology including limestones, marl, and shales. The evaluation is based on results of TOC, Rock-Eval pyrolysis, and vitrinite reflectance analyses for ditch cuttings from 5 wells. Besides, constructing 1d basin models for several wells took place in the present study to estimate the generation timing. The geochemical results show that the Upper Jurassic contains poor to good organic quantity with poor to good hydrocarbon generating potential of type II/III and type III kerogen. The Lower Cretaceous rocks are poor to very good in terms of organic richness and hydrocarbon generating potential as well and belong to type II/III and minor type III kerogen. Moreover, a poor to good richness was encountered for the Upper Oligocene, with poor to fair hydrocarbon generation potential of kerogen type III. 1d basin modeling results indicate that three main tectonic phases influenced the burial history comprising the Jurassic-Cretaceous rift, the Late Cretaceous-Oligocene uplift associated with the Syrian arc folding, and the Late Miocene rift. These movements affected the thermal maturity in the studied area. The Upper Oligocene source rock is immature to early mature in most of the studied wells, whereas the Lower Cretaceous and Upper Jurassic source rocks were entered the main stage of hydrocarbon generation earlier in the eastern wells than the western wells, related to a variant tectonic impact in the area. The top oil window was reached at depth ranges from 2300 m in Mango-3 well to 4000 m in Hout-1 well, while the base of the oil window is found only in Mango-1 well at 4300 m depth.

关键词： Source rock evaluation 1d basin modeling Maturity modeling Offshore North Sinai Egypt

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Burial and thermal history simulation of the subsurface Paleozoic source rocks in Faghur basin, north Western desert, Egypt: Implication for hydrocarbon generation and expulsion history

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Egyptian Journal of Petroleum 2019年第3期28卷 261-271页

作者： Abd El Gawad, Esam A. Ghanem, Mohamed F. Lotfy, Mostafa M. Mousa, doaa A. Temraz, Mostafa G. Shehata, Amr M. Geology Department Faculty of Science Al-Azhar University P.O. Box 11884 Egypt Exploration Department Egyptian Petroleum Research Institute (EPRI) 1 Ahmed El Zommor st. Nasr City Cairo 11727 Egypt

Paleozoic Zeitoun, desouqy and dhiffah formations represent source rocks to hydrocarbon in Faghur basin, north Western desert, Egypt. They are characterized by a sufficient amount of organic matter belonging to kerogen type III and mixed type II/III, which are in maturation stage. A 1d-basin modeling was performed by using geological and geochemical data of the Paleozoic source rocks from five wells in Faghur basin, north Western desert, Egypt. These data used in 1d basin modeling for constructing and understanding of burial and thermal geo-histories of Faghur basin and for simulating and predicting the timing of petroleum and expulsion for the Paleozoic source rocks in the studied wells. Burial and thermal history models indicate that the Zeitoun Formation entered onset of oil generation in the studied wells during Late Cretaceous (100.10–91.65 my) with transformation ratio (TR) 10–25, peak oil during Late Cretaceous (91.65–79.30 my) with TR 25–50 and late oil stage at Late Cretaceous (79.30 my-0) to present day with TR 50–60.45. desouqy Formation entered onset of oil generation also during Late Cretaceous (94.43–73.60 my) with TR 10–25 in the studied wells, peak oil during Late cretaceous (73.60–62.40 my) with TR 25–50 and Late oil stage during Late Cretaceous to present day (62.40 my-0) with TR 50–61.82. dhiffah Formation entered onset of oil generation in the studied wells during Early to Late Cretaceous (102.11–92.27 my) with TR 10–25, peak oil during Late Cretaceous (92.27–86.40 my) with TR 25–50 and late oil stage at Late Cretaceous to present day (86.40 my-0) with TR 50–67.27. No cracking oil to gas in the studied Paleozoic source rocks in the studied wells. These basin modeling results also suggest that the Paleozoic source rocks act as an effective source rock where a significant amount of petroleum is expected to be generated and expelled to any nearby prospect reservoir rocks in the Faghur basin. © 2019 Egyptian Petroleum Research Institute

关键词： 1d basin modeling Faghur basin Hydrocarbon generation and expulsion Paleozoic source rocks Transformation ratio (TR)

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Numerical modeling of the Tectonic and Thermal History of the Kyndal Graben of the Bureya basin (Far East of Russia)

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RUSSIAN JOURNAL OF PACIFIC GEOLOGY 2017年第3期11卷 205-222页

作者： Razvozzhaeva, E. P. Prokhorova, P. N. Lapkovskii, V. V. Russian Acad Sci Far East Branch Kosygin Inst Tecton & Geophys Ul Kim Yu Chena 65 Khabarovsk 680000 Russia Russian Acad Sci Siberian Branch Trofimuk Inst Petr Geol & Geophys Pr Akad Koptyuga 3 Novosibirsk 630090 Russia

One-dimensional basin modeling of the Kyndal Graben, Bureya basin, is conducted in three deep wells. The basin modeling technique and its basic algorithms are described. The geological and geophysical characteristics of the studied object are reported in brief, emphasizing the modeling parameters. The general and tectonic history of the subsidence, sedimentation velocities, geodynamic parameters of the extension, and thermal history of the formation and evolution of the Kyndal Graben, Bureya basin, are calculated.

关键词： 1d basin modeling subsidence history backstripping method riftogenesis McKenzie model thermal history Kyndal Graben Bureya basin Far East of Russia

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