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Academic literature on the topic 'Petroleum – Geology – China'

Author: Grafiati

Published: 10 December 2022

Last updated: 31 January 2023

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Journal articles on the topic "Petroleum – Geology – China"

1

Zou, Caineng, Shizheng Tao, Zhi Yang, Lianhua Hou, Xuanjun Yuan, Rukai Zhu, Jinhua Jia, et al. "Development of petroleum geology in China: Discussion on continuous petroleum accumulation." Journal of Earth Science 24, no. 5 (October 2013): 796–803. http://dx.doi.org/10.1007/s12583-013-0373-7.

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KOMATSU, NAOMOTO. "Current topics on the petroleum geology in China." Journal of the Japanese Association for Petroleum Technology 51, no. 2 (1986): 138–44. http://dx.doi.org/10.3720/japt.51.138.

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3

Desheng, Li. "RECENT ADVANCES IN THE PETROLEUM GEOLOGY OF CHINA." Journal of Petroleum Geology 13, no. 1 (January 1990): 7–18. http://dx.doi.org/10.1111/j.1747-5457.1990.tb00248.x.

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4

Wang, Bing, Harry Doust, and Jingyan Liu. "Geology and Petroleum Systems of the East China Sea Basin." Energies 12, no. 21 (October 26, 2019): 4088. http://dx.doi.org/10.3390/en12214088.

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The back-arc East China Sea Basin lies on extended continental crust at the leading edge of the Eurasian plate. In this study, the basins are described and subdivided according to their tectono-stratigraphic evolution. In order to distinguish between different phases of deformation in basin development, standard basin evolution patterns related to geodynamic drivers are identified as a first step. On the basis of this, standard patterns are recognized in the sedimentary sequences that characterize the area and its tectonic evolution, and linking them to the petroleum systems present is attempted. This is achieved by characterizing and grouping them into basin cycle-related petroleum system types (PSTs). Finally, the development of plays is examined within the petroleum systems in the context of their tectono-stratigraphic evolution, and groups of sub-basins with similar geological history and, therefore, potentially similar petroleum prospectivity are identified. In the East China Sea Basin, four proven and potential PSTs were recognized: (1) Late Cretaceous to Paleocene oil/gas-prone early syn-rift lacustrine–deltaic PST; (2) Eocene gas/oil prone late syn-rift marine PST; (3) Oligocene to Middle Miocene gas/oil-prone early post-rift fluvial–deltaic PST; (4) gas-prone syn-rift turbiditic PST. The geology and petroleum systems of three major sub-basins of the East China Sea Basin, the Xihu Sub-basin, the Lishui Sub-basin, and Okinawa Trough, are discussed in detail, and their petroleum systems and play development are analyzed. Finally, the sub-basins are grouped into “basin families” distinguished by their tectono-stratigraphic development, namely, Northwest to Northeast Shelf Basin (NWSB–NESB), Southwest to Southeast Shelf Basin (SWSB–SESB), and Okinawa Trough basin families, respectively.

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Wang, Jian Guo, Hai Jie Zhang, Cui Cui Liu, and Li Xia Lou. "The Significance of Shale Gas Development in China." Advanced Materials Research 616-618 (December 2012): 767–69. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.767.

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China is facing a severe situation of energy resources. High oil dependency is seriously threatening our economy’s fast and stable development. The US has successfully achieved the commercial development of shale gas, which has decreased its oil dependency, and also contributed to its natural gas geology and petroleum engineering technology development. Both Chinese and U.S. geological experts predict that China has similar quantities of shale gas reserves as founded in the United States. This paper aims to clarify that producing shale gas resources has economic significance of energy security and environment protection, and scientific significance of promoting the further development of natural gas geology and petroleum engineering subjects.

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JIANG, DE-XIN, YONG-DONG WANG, ELEANORA I. ROBBINS, JIANG WEI, and NING TIAN. "Mesozoic non-marine petroleum source rocks determined by palynomorphs in the Tarim Basin, Xinjiang, northwestern China." Geological Magazine 145, no. 6 (July 30, 2008): 868–85. http://dx.doi.org/10.1017/s0016756808005384.

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AbstractThe Tarim Basin in Northwest China hosts petroleum reservoirs of Cambrian, Ordovician, Carboniferous, Triassic, Jurassic, Cretaceous and Tertiary ages. The sedimentary thickness in the basin reaches about 15 km and with an area of 560000 km2, the basin is expected to contain giant oil and gas fields. It is therefore important to determine the ages and depositional environments of the petroleum source rocks. For prospective evaluation and exploration of petroleum, palynological investigations were carried out on 38 crude oil samples collected from 22 petroleum reservoirs in the Tarim Basin and on additionally 56 potential source rock samples from the same basin. In total, 173 species of spores and pollen referred to 80 genera, and 27 species of algae and fungi referred to 16 genera were identified from the non-marine Mesozoic sources. By correlating the palynormorph assemblages in the crude oil samples with those in the potential source rocks, the Triassic and Jurassic petroleum source rocks were identified. Furthermore, the palynofloras in the petroleum provide evidence for interpretation of the depositional environments of the petroleum source rocks. The affinity of the miospores indicates that the petroleum source rocks were formed in swamps in brackish to lacustrine depositional environments under warm and humid climatic conditions. The palynomorphs in the crude oils provide further information about passage and route of petroleum migration, which is significant for interpreting petroleum migration mechanisms. Additionally, the thermal alternation index (TAI) based on miospores indicates that the Triassic and Jurassic deposits in the Tarim Basin are mature petroleum source rocks.

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7

ABE, Hiroshi. "Petroleum geology of the beibu gulf, People's Republic of China." Journal of the Japanese Association for Petroleum Technology 54, no. 1 (1989): 43–51. http://dx.doi.org/10.3720/japt.54.43.

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8

Changlin, Gao, and Ye Deliao. "PETROLEUM GEOLOGY OF THE TARIM BASIN, NW CHINA: RECENT ADVANCES." Journal of Petroleum Geology 20, no. 2 (April 1997): 239–44. http://dx.doi.org/10.1111/j.1747-5457.1997.tb00775.x.

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9

Xiao, X. M., B. Q. Zhao, Z. L. Thu, Z. G. Song, and R. W. T. Wilkins. "Upper Paleozoic petroleum system, Ordos Basin, China." Marine and Petroleum Geology 22, no. 8 (September 2005): 945–63. http://dx.doi.org/10.1016/j.marpetgeo.2005.04.001.

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10

G, Shanmugam. "100 years of the Devine Teacher - Student relationship among the three Generations of Indian Geoscientists (1920s – 2020s): A remarkable Story of Knowledge transfer from T. N. Muthuswami Iyer “TNM” through A. Parthasarathy to G. Shanmugam and beyond." Journal of The Indian Association of Sedimentologists 1, no. 1 (December 31, 2022): 2–40. http://dx.doi.org/10.51710/jias.v1i1.221.

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The divine teacher-student relationship that covers 100 years of knowledge transfer is the underpinning of this remarkable personal story. Importantly, this narrative is about an Indian genius and a geologic pioneer, Professor T. N. Muthuswami Iyer, known as TNM. The first generation (1920s-1960s) TNM began his teaching career as a crystallographer and a mineralogist at the University of Madras-Gundy Campus (Chennai) in 1924, and continued at the Presidency College (Madras), Sager University (Madhya Pradesh), and Annamalai University (Tamil Nadu). One of his early students at Presidency was A. Parthasarathy, who later studied at the Imperial College in London (UK) and earned his Ph.D. in Engineering Geology from the London University (UL) in 1954. The second generation (1940s-1980s) Prof. Parthasarathy became the Head of Applied Geology section in the Civil Engineering Department at the Indian Institute of Technology (IIT) Bombay in 1964. The third generation (1960s-2020s) G. Shanmugam earned his B.Sc. in Geology and Chemistry from Annamalai University with a First Class (1965) and started teaching science in a local high school in his hometown of Sirkazhi, Tamil Nadu. TNM, who was the Head of Geology at Annamalai University in 1965, motivated G. Shanmugam to quit his teaching job and pursue M.Sc. in Applied Geology at IIT Bombay. Shanmugam earned his M.Sc. in Applied Geology at IIT Bombay under the guidance of Prof. Parthasarathy. Education and training at IIT Bombay propelled Shanmugam to receive his second M.S. and Ph.D. degrees in the USA. His Ph.D. research under the guidance of Prof. Kenneth R. Walker at University of Tennessee on Ordovician tectonics and sedimentation in the Southern Appalachians led to securing a research position with Mobil Oil Company in Dallas, Texas in 1978. Because of his global research on multiple domains while at Mobil and as post-retirement consultant since 2000 for oil companies in India and China, Shanmugam has to his credit 382 published works that include three Elsevier books on process sedimentology and petroleum geology, with the first two books were translated into Chinese language. He has authored 6 invited Encyclopedia Chapters for Elsevier and McGraw Hill Book Companies and has delivered 89 lectures worldwide during 1980-2021 period. He won the top "Special Prize" from Springer Journal of Palaeogeography in 2020 for "Excellent Papers" based on Science Citation Index (SCI) of five articles published during 2012-2018. Shanmugam's efforts in knowledge transfer during the COVID-19 global pandemic included giving virtual lectures on Zoom, Google Meet, and WebEx platforms to academia (e.g., Royal Holloway, University of London, IIT Bombay, and Ohio University). Shanmugam organized 23 onsite workshops on "Deep-water sandstone petroleum reservoirs" worldwide, which included (1) the UK Government Department of Trade and Industry (DTI), Edinburgh, UK, (2) Reliance Industries Ltd., Kakinada, India, (3) Hardy Oil, Chennai, India, (4) Oil and Natural Gas Corporation (ONGC), Mumbai and Kajuraho, India, (5) Petrobras, Rio de Janeiro, Brazil, (6) Research Institute of Petroleum Exploration and Development (RIPED) of PetroChina, Beijing, China, and (7) China University of Petroleum, Qingdao, China. The T. N. Muthuswami - A. Parthasarathy - G. Shanmugam lineage, spanning over 100 years, is unique and phenomenal in knowledge transfer among geoscientists. On the economic front, TNM and his lineages contributed directly to the petroleum, atomic mineral, cement, gemstone, and geothermal energy industries, among many others. The acronym "TNM" for T. N. Muthuswami Iyer is just perfect for a Transformational, Neoteric and a Motivating teacher and a noble soul!

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Books on the topic "Petroleum – Geology – China"

1

Zhai, Guangming. Petroleum geology of China. Beijing, P.R. China: Petroleum Industry Press, 1997.

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2

Hu, Jianyi. Nonmarine petroleum geology of China. Beijing: Petroleum Industry Press, 1996.

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3

Jia, Chengzao. Tectonic characteristics and petroleum, Tarim Basin, China. Beijing, P.R.C: Petroleum Industry Press, 1997.

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4

Hu, Jianyi. Advances in petroleum geology and exploration in China. Beijing: Petroleum Industry Press, 1996.

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5

Wang, Tieguan. Meso-Neoproterozoic Geology and Petroleum Resources in China. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9.

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6

1918-, Wagner Holly Clyde, Circum-Pacific Council for Energy and Mineral Resources., and Beijing Petroleum Symposium (1984), eds. Petroleum resources of China and related subjects. Houston, Tex., U.S.A: Published by the Circum-Pacific Council for Energy and Mineral Resources, 1989.

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7

Lee, K. Y. Geology of petroleum and coal deposits in the North China basin, Eastern China. Washington, D.C: U.S. G.P.O., 1989.

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8

Lee, K. Y. Geology of petroleum and coal deposits in the North China basin, Eastern China. Washington, DC: Dept. of the Interior, 1989.

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9

Qiu, Yinan. Continental hydrocarbon reservoirs of China. Beijing: Petroleum Industry Press, 1997.

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10

Ulmishek, Gregory F. Geology and hydrocarbon resources of onshore basins in eastern China. [Denver, Colo.]: U.S. Dept. of the Interior, U.S. Geological Survey, 1992.

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Book chapters on the topic "Petroleum – Geology – China"

1

Jia, Chengzao. "Oil and Gas Resources in China." In Characteristics of Chinese Petroleum Geology, 111–50. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-23872-7_3.

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2

Jia, Chengzao. "Petroleum Geology of Foreland Thrust Belts in China." In Characteristics of Chinese Petroleum Geology, 333–421. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-23872-7_9.

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3

Shan-shu, Wang. "The Geology and Petroleum Resources of Northern China Seas." In Oceanology of China Seas, 347–60. Dordrecht: Springer Netherlands, 1994. http://dx.doi.org/10.1007/978-94-011-0862-1_34.

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Wang, Shan-shu. "The Geology and Petroleum Resources of Northern China Seas." In Oceanology of China Seas, 347–60. Dordrecht: Springer Netherlands, 1994. http://dx.doi.org/10.1007/978-94-011-0886-7_1.

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5

Xianhua, Li, and Li Wuxian. "Neoproterozoic Magmatism and Tectonic Evolution in South China." In Meso-Neoproterozoic Geology and Petroleum Resources in China, 319–59. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9_9.

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6

Gao, Linzhi, Xiaozhong Ding, Heng Zhang, Xiufu Qiao, Chongyu Yin, Xiaoying Shi, and Chuanheng Zhang. "Advances in Meso-Neoproterozoic Isotopic Chronostratigraphy in China." In Meso-Neoproterozoic Geology and Petroleum Resources in China, 1–45. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9_1.

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Liu, Pengju, Chongyu Yin, and Feng Tang. "Research Progress of Ediacaran (Sinian) Biostratigraphy in South China." In Meso-Neoproterozoic Geology and Petroleum Resources in China, 155–79. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9_4.

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Han, Keyou, Wei Sun, and Dan Li. "Sinian Gas Prospectivity in the Western Yangtze Craton, Southwest China." In Meso-Neoproterozoic Geology and Petroleum Resources in China, 485–509. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9_13.

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9

Zhai, Mingguo, Bo Hu, Peng Peng, Taiping Zhao, and Qingren Meng. "Meso-Neoproterozoic Multiple Rifting and Magmatism in the North China Craton." In Meso-Neoproterozoic Geology and Petroleum Resources in China, 277–318. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9_8.

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10

Luo, Shunshe, Zhenzhong Gao, Hongwei Kuang, Yuan Shao, and Mingli Xi. "Meso-Neoproterozoic Sequence Stratigraphy, Sedimentary Facies and Source-Reservoir-Seal Bed Assemblage in Jibei Depression, Yanliao Faulted-Depression Zone." In Meso-Neoproterozoic Geology and Petroleum Resources in China, 91–154. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-5666-9_3.

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Conference papers on the topic "Petroleum – Geology – China"

1

Liu, Wei, Zhenhua He, Junxing Cao, Jianjun Zhang, Gang Xu, Xiaoping Wan, and Gang Yu. "Integrated Geology Sweet Spot and Microseismic Monitor to Optimise Reservoir Stimulation - A Case for Shale Gas, China." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2019. http://dx.doi.org/10.2523/19197-ms.

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Liu, Wei, Zhenhua He, Junxing Cao, Jianjun Zhang, Gang Xu, Xiaoping Wan, and Gang Yu. "Integrated Geology Sweet Spot and Microseismic Monitor to Optimise Reservoir Stimulation - A Case for Shale Gas, China." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2019. http://dx.doi.org/10.2523/iptc-19197-ms.

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3

Hon, Vai Yee, M. Faizzudin Mat Piah, Noor 'Aliaa M Fauzi, Peter Schutjens, Binayak Agarwal, and Rob Harris. "Integrated Reservoir Geomechanics Approach for Reservoir Management." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21216-ms.

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Abstract An integrated 3D dynamic reservoir geomechanics model can provide a diverse 3D view of depletion-injection-induced field stress changes and the resulting deformation of both reservoir and overburden formations at various field locations. It enables the assessment of reservoir compaction, platform site subsidence, fault reactivation and caprock integrity associated with multiple production and injection reservoirs of the field. We demonstrated this integrated approach for a study field located in the South China Sea, Malaysia, which is planned for water injection for pressure support and EOR scheme thereafter. Reservoir fluid containment during water injection is an important concern because of the intensive geologic faulting and fracturing in the collapsed anticlinal structure, with some faults extending from the reservoirs to shallow depths at or close to the seafloor. Over 30 simulations were done, and most input parameters were systematically varied to gain insight in their effect on result that was of most interest to us: The tendency of fault slip as a function of our operation-induced variations in pore pressure in the reservoir rocks bounding the fault, both during depletion and injection. The results showed that depletion actually reduces the risk of fault slip and of the overburden, while injection-induced increase in pore fluid pressure will lead to a significant increase in the risk of fault slip. Overall, while depletion appears to stabilize the fault and injection appears to destabilize the fault, no fault slip is predicted to occur, not even after a 900psi increase in pore pressure above the pore pressure levels at maximum depletion. We present the model results to demonstrate why depletion and injection have such different effects on fault slip tendency. The interpretation of these geomechanical model results have potential applications beyond the study field, especially for fields with a similar geology and development plan. This is a novel application of 3D dynamic reservoir geomechanics model that cannot be obtained from 1D analytical models alone.

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4

Yu, Jingfeng, Diao Zhou, Bo Zhang, Haiping Meng, Tong Li, Li Wang, Yong Wang, et al. "Horizontal Well Drilling and Geosteering Optimization with Integrated Innovation Technologies: Case Studies from the World Largest Conglomerate Reservoir in West China." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21482-ms.

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Abstract MH oilfield is a fan delta deposited unconventional tight oil reservoir with complex lithology of volcanic rocks, metamorphic rocks, conglomerate, and claystone. The drilling efficiency was optimized by using the first-generation boundary mapping technology with Rotary Steering System (RSS) during the first batch drilling campaign (H2-2016∼H1-2017), which was mentioned in IADC/SPE-190998-MS. But with the development going further, more and more wells drilled into shale interbed causing low pay zone exposure, long drilling duration, and numerous drilling hazards. The overall drilling performance was not optimistic as before, the average Rate Of Penetration (ROP) decreased by 30.7% and the average footage per run decreased by 38.9% during horizontal section operation in some specific blocks of MH oilfield. By reviewing the detailed drilling and geology material of the first batch drilling, the challenges were defined. There is lateral irregular thin shale interbed existing in this conglomeratic reservoir which is rarely observed from the nearby wells in the first batch drilling zone. That unstable shale interbed with 0.5-2m thickness isolated the target into 2 to 3 components. The first-generation boundary mapping technology can only detect the nearest up or down boundary, with this limitation, it is difficult to reveal these laterally unstable shale interbed. It is crucial to precisely delineate the irregular thin interbed to develop this complex reservoir. Meanwhile, the bit selection which didn't catch up with the formation change is another issue that needs to be optimized timely. To solve the above challenges, the new generation boundary mapping while drilling technology was introduced to this project, it has 3 or more boundaries detecting ability at the same time, which can delineate the irregular thin interbed and optimize real-time Well Placement decision making. Meanwhile, the bit design and selection based on the timely geological data interpretation helped to improve drilling efficiency. This innovative integrated method deployed in phase II horizontal well drilling campaign proved to be an effective approach to optimize geosteering and drilling performance. The clear reservoir geometry delineation effectively helps avoid entering the irregular shale interbed in real-time, thus improve the pay zone exposure and trajectory smoothness. Till 2018, more than 50 wells were completed, the overall drilling performance of 2018 has been improved by 47.2% of footage per run and 42.2% of ROP compared with statistical results of H2-2017 of the M131 block and nearly back to the normal level. In this paper, the authors will demonstrate how this integrated approach helps optimize Well Placement, enhance drilling efficiency and save budget with some exemplary case studies. With this success, the authors believe this approach and techniques could effectively address the following horizontal well drilling campaign in this unconventional tight oil reservoir.

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Dan, Lingling, Changlin Shi, Jiatao Wen, Yunting Hu, Li Wei, Yunxiu Li, Jian Zhang, and Panpan Tian. "Application of Multi-Information Fusion Fracture Modelling Based on Neural Network in Carbonate Dual: Medium Reservoir." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21389-ms.

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Abstract G oilfield in China is a dual medium oilfield dominated by carbonate reservoir, where faults and fractures are well developed. After G oilfield was put into production, water cut has rised quickly and oil production decreased rapidly. The heterogeneity of fracture development is very strong. Because of unclear understanding of the fracture distribution, oilfield development plan can not accurately identify risks and potentials accurately. As a result, production goals are not as expected. Due to limited core data and imaging logging data, conventional methods cannot characterize fracture information in this oilfield accurately and comprehensively. In order to solve the problems mentioned above, this paper makes full use of logging, geology, seismic and other data to carry out fine characterization of fracture with multi-information fusion fracture modeling based on neural network. Firstly, neural network technology is used to predict the fracture density curves of wells with conventional logging data. Secondly, combined the nonlinear fusion of multiple pre-stack seismic attributes including Tectonic Stress Field, P-Wave AVO and Seismic Discontinuity Detection based on neural network, the fracture density probability model is created to predict three-dimensional distribution of fractures. Thirdly, the fracture Intensity model is set up under the constraint of strict variation function analysis and fracture density probability model. Finally, fracture parameters are obtained according to core observation and imaging logging data, and the fracture network is established by geostatistics modeling method and coarsened equivalent into fracture property model. Blind well validation and dynamic validation are used to verify the validity of fracture model. Under the guidance of research results in this paper, the oilfield development plan is optimized and adjusted. It has also been proved that fracture characteristic of new wells is consistent with pre-drilling prediction result. Most areas with relatively high fracture development degree are corresponding to well groups with faster water cut rising rate. Against the backdrop of global oil economic downturn, fracture modeling technology studied in this paper provides strong technical guidance for oilfield development plan, therefore reducing oilfield development risks and maximizing economic benefits.

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Abd Karim, Rahimah Binti, and Roberto Aguilera. "Vaca Muerta: An Emerging Shale Petroleum Reservoir." In SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205573-ms.

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Abstract Argentina is ranked second globally in terms of technically recoverable shale gas, and fourth in shale oil (EIA 2015). The most prolific shale is the Vaca Muerta formation. The objective of this paper is to present geological and reservoir characterization, drilling and production strategies, as well as historical performance and economics of Vaca Muerta. The word petroleum as used in this paper includes oil, natural gas, and natural gas liquids. This paper describes natural fractures and their impact on hydrocarbon productivity. The successful commercial production from this unconventional resource has been driven by many factors, including regional geology, availability of advanced technology such as horizontal drilling and multi-stage hydraulic fracturing, as well as domestic and regional hydrocarbon demand (Sierra 2016). Vaca Muerta itself is very unique with multiple hydrocarbon windows from east to west, ranging from dry gas to wet gas, to light oil and black oil. The productivity of Vaca Muerta is benchmarked to some of the best US shale plays such as the Eagle Ford and the Marcellus. Vaca Muerta contains 1202 Tcf of risked gas in-place and 270 billion barrels of risked oil in-place. It is estimated that 308 Tcf and 16 billion barrels of these resources are technically recoverable (EIA 2015). To date, the total number of horizontal wells exceeds 600, mostly drilled in the black oil window (Secretaria de Energia de Argentina 2020; Wood Mackenzie 2020b). Dubbed the ‘golden goose’ of Argentina, the last decade has seen rapid exploration and development activities. The Argentina state oil company (YPF) leads the development in this region together with its partners. In 2019, production from Vaca Muerta reached 90,000 bbl/d of oil and 1180 MMcf/d of gas, contributing 21% of Argentina's total production (Secretaria de Energia de Argentina 2020; Wood Mackenzie 2020b). YPF predicted these rates would increase by 150% in 2022 (Rassenfoss 2018). Part of this increase will be contributed by La Amarga Chica block, where YPF and its partner, PETRONAS approved their 30-year master development plan in late 2018 to deliver 54,000 boe/d by 2022 (Zborowski 2019). This production increase has obviously been delayed due to the COVID-19 pandemic. The novelty of this paper is integration of geological and reservoir characterization, drilling and production strategies, as well as historical performance and economics of Vaca Muerta. It is concluded that oil and gas potential in the Vaca Muerta shale is significant and rivals the potential of some of the shales widely developed in the Unites States and Canada.

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7

Jia, Ying, Yunqing Shi, and Jin Yan. "The Feasibility Appraisal for CO2 Enhanced Gas Recovery of Tight Gas Reservoir: Case Analysis and Economic Evaluation." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21291-ms.

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Abstract Tight gas reservoirs are widely distributed in China, which occupies one-third of the total resources of natural gas. The typical development method is under primary depletion. However, the recovery of tight gas is only around 20%. It is necessary to explore a new technique to improve tight gas recovery. Injecting CO2 into tight gas reservoirs is a novel trial to enhance gas recovery. The objective of this work is to verify and evaluate the effect supercritical CO2 on enhancing gas recovery and analyze the feasibility of CO2 enhance gas recovery of tight gas reservoir. Taken DND tight sandstone gas reservoir in North China as an example, 34 wells of DK13 wellblock were chosen as CO2 Enhanced gas recovery pilot area with 10-year production history. Six injection scenarios were studied. Numerical simulation indicated that the recovery of the gas reservoir of DK13 well area was improved by 8-9.5 percent when CO2 content of producers reaches 10 percent. The annual CO2 Storage would be 62 million cubic meters (110 thousand tons) and the total CO2 storage would be around 800million cubic meters (1.5 million tons). After the environmental parameter evaluation of injectors and producers, the anticorrosion schemes were put forward and the feasibility evaluation and schemes of facilities were presented. The analysis results indicated that DK13 wellblock was suitable for CO2 enhanced gas recovery no matter geologic condition, injection & production technology and facilities. However, under the current economic conditions, DK13 wellblock was not suitable for CO2to enhance gas recovery. However, if gas price rise or low carbon strategy implement, the pilot test could be carried out. In brief, CO2 could be an attractive option to successfully displace natural gas and decrease CO2 emissions, which is a promising technology for reducing greenhouse gas emission and increasing the ultimate gas recovery of tight gas reservoirs. This economic analysis, along with reservoir simulation and laboratory studies that suggest the technical feasibility of CSEGR, demonstrates that CSEGR can be feasible and that a field pilot study of the process should be undertaken to test the concept further.

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Reports on the topic "Petroleum – Geology – China"

1

Geology of petroleum and coal deposits in the North China Basin, Eastern China. US Geological Survey, 1989. http://dx.doi.org/10.3133/b1871.

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Geologic framework, petroleum potential, and field locations of the sedimentary basins in China. US Geological Survey, 1988. http://dx.doi.org/10.3133/i1952.

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