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Journal articles on the topic 'Petroleum reservoir'

Author: Grafiati

Published: 4 June 2021

Last updated: 26 July 2025

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1

Barbosa, Gustavo Santana, Gustavo Gonçalves Garcia, Rui Paulo Bento Pena dos Reis, Antônio Jorge Vasconcellos Garcia, and Gabriel de Alemar Barberes. "Analysis of the Efficiency of Petroleum Systems in Fluvial Environments in the Rift Context of the South and North Atlantic: Brazil and Portugal." Geosciences 13, no. 8 (2023): 239. http://dx.doi.org/10.3390/geosciences13080239.

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The present article exhibits the achieved results based on the evaluation of two petroleum systems, which compares reservoirs of fluvial environments of sedimentary basins located in the south and north Atlantic, in Brazil (Recôncavo Basin) and in Portugal (Lusitanian Basin), respectively. The main contribution of this study is the survey of the static (source, reservoir, and sealing rocks, in addition to traps) and dynamic elements (tectonic, migration, thermal, and diagenetic processes) of the two studied petroleum systems, seeking to understand the reasons for the success and failure of the

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2

Wang, Jing Yi, Shang Ming Shi, and Xian Li Du. "Beier Depression Petroleum System Study in Hailaer." Applied Mechanics and Materials 668-669 (October 2014): 1546–49. http://dx.doi.org/10.4028/www.scientific.net/amm.668-669.1546.

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Through the study of Beier depression accumulation critical moment, divided into three sets of petroleum system in beier depression: passive faulted depression primary petroleum system, active faulted depression primary petroleum system and fault depression transform secondary petroleum system. Through the typical reservoir oil-water distribution rule and reservoir dissect result can get to know oil and gas of Beier depression concentration distribute in passive faulted depression sequence petroleum system, mainly develop reverse fault block reservoir as well as buried hill reservoir blocked b

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3

Liu, Q., H. Xu, Z. Lei, et al. "Fault Mesh Petroleum Plays in the Donghetang Area, Tabei Uplift, Tarim Basin, Northwestern China, and Its Significance for Hydrocarbon Exploration." Russian Geology and Geophysics 62, no. 07 (2021): 808–27. http://dx.doi.org/10.2113/rgg20183939.

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Abstract —The hydrocarbon formation mechanism and potential targets in clastic strata from the Tabei Uplift, Tarim Basin, are documented using the fault mesh petroleum plays theory, based on integrating seismic, well log, well core, and geochemical data. The reservoirs in the Donghetang area are typical allochthonous and far-source fault mesh petroleum plays. There are two sets of fault meshes in the study area: (1) the combination of the Donghe sandstone and Permian–Triassic strata and (2) the combination of the fourth and third formations in the Jurassic strata. The fault mesh petroleum play

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4

Nystad, Arild N. "PETROLEUM RESERVOIR MANAGEMENT: A RESERVOIR ECONOMIC APPROACH." Natural Resource Modeling 2, no. 3 (1988): 345–82. http://dx.doi.org/10.1111/j.1939-7445.1988.tb00064.x.

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5

Amer, Manar M., and Dahlia A. Al-Obaidi. "Methods Used to Estimate Reservoir Pressure Performance: A Review." Journal of Engineering 30, no. 06 (2024): 83–107. http://dx.doi.org/10.31026/j.eng.2024.06.06.

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Reservoir pressure plays a significant role in all reservoir and production engineering studies. It is crucial to characterize petroleum reservoirs: by detecting fluid movement, computing oil in place, and calculating the recovery factor. Knowledge of reservoir pressure is essential for predicting future production rates, optimizing well performance, or planning enhanced oil recovery strategies. However, applying the methods to investigate reservoir pressure performance is challenging because reservoirs are large, complex systems with irregular geometries in subsurface formations with numerous

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6

Lawal, Kazeem A. "Applicability of heat-exchanger theory to estimate heat losses to surrounding formations in a thermal flood." Journal of Petroleum Exploration and Production Technology 10, no. 4 (2019): 1565–74. http://dx.doi.org/10.1007/s13202-019-00792-5.

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Abstract Heat losses to cap and base rocks undermine the performance of a thermal flood. As a contribution to this subject, this paper investigates the applicability of the principles of heat exchanger to characterise heat losses between a petroleum reservoir and the adjacent geologic systems. The reservoir-boundary interface is conceptualised as a conductive wall through which the reservoir and adjacent formations exchange heat, but not mass. For a conduction-dominated process, the heat-transport equations are formulated and solved for both adiabatic and non-adiabatic conditions. Simulations

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7

Gutierrez, M., R. W. Lewis, and I. Masters. "Petroleum Reservoir Simulation Coupling Fluid Flow and Geomechanics." SPE Reservoir Evaluation & Engineering 4, no. 03 (2001): 164–72. http://dx.doi.org/10.2118/72095-pa.

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Summary This paper presents a discussion of the issues related to the interaction between rock deformation and multiphase fluid flow behavior in hydrocarbon reservoirs. Pore-pressure and temperature changes resulting from production and fluid injection can induce rock deformations, which should be accounted for in reservoir modeling. Deformation can affect the permeability and pore compressibility of the reservoir rock. In turn, the pore pressures will vary owing to changes in the pore volume. This paper presents the formulation of Biot's equations for multiphase fluid flow in deformable porou

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8

Wu, Haisheng, Shuai Sun, Menglin Zheng, et al. "Reservoir Overpressure in the Mahu Sag, Northwestern Junggar Basin, China: Characteristics and Controlling Factors." Geofluids 2023 (January 6, 2023): 1–15. http://dx.doi.org/10.1155/2023/2422666.

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Reservoirs with overpressure are of great importance for petroleum exploration where commercial production can be usually obtained. Studying the distribution characteristics and controlling factors of reservoir overpressure is crucial for further petroleum exploration. In this study, we investigate the vertical and planar distribution of reservoir overpressure in the Mahu sag, northwestern Junggar basin by analyzing measured pressure data from well testing of oil reservoirs. In the Baikouquan-Jiamuhe Formation, reservoir overpressure is widely distributed, and the pressure coefficient increase

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9

Pierpont, Rob, Kristoffer Birkeland, Alexandra Cely, et al. "Enigmatic Reservoir Properties Deciphered Using Petroleum System Modeling and Reservoir Fluid Geodynamics." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 64, no. 1 (2023): 6–17. http://dx.doi.org/10.30632/pjv64n1-2023a1.

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Two adjacent reservoirs in offshore oil fields have been evaluated using extensive data acquisition across multiple disciplines; several surprising observations were made. Differing levels of biodegradation were measured in the nearly adjacent reservoirs, yet related standard geochemical markers are contradictory. Unexpectedly, the more biodegraded oil had less asphaltene content, and this reservoir had some heavy end deposition in the core but upstructure, not at the oil-water contact (OWC) as would be expected, especially with biodegradation. Wax appears to be an issue in the nonbiodegraded

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10

Qin, Yaqiong, Zhaohui Ye, and Conghui Zhang. "Application of deep learning for division of petroleum reservoirs." MATEC Web of Conferences 246 (2018): 03004. http://dx.doi.org/10.1051/matecconf/201824603004.

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Traditional methods of dividing petroleum reservoirs are inefficient, and the accuracy of onehidden-layer BP neural network is not ideal when applied to dividing reservoirs. This paper proposes to use the deep learning models to solve the reservoir division problem. We apply multiple-hidden-layer BP neural network and convolutional neural network models, and adjust the network structures according to the characteristics of the reservoir problem. The results show that the deep learning models are better than onehidden- layer BP neural network, and the performance of the convolutional neural net

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11

Shemin, G. G., P. A. Glazyrin, A. G. Vakhromeev, et al. "PETROLEUM POTENTIAL QUANTITATIVE FORECAST OF DEEPLY-BURIED REGIONAL RESERVOIRS OF THE LOWER JURASSIC DEPOSITS WITHIN THE YENISEI-KHATANGA AND EASTERN GYDAN PETROLEUM REGIONS OF THE SIBERIAN SECTOR IN THE ARCTIC." Geology and mineral resources of Siberia, no. 4 (December 2021): 38–57. http://dx.doi.org/10.20403/2078-0575-2021-4-38-57.

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The article presents the results of petroleum potential quantitative forecast of the Toarcian, Pliensbachian and Hettangian-Sinemurian regional reservoirs of Lower Jurassic deep-buried deposits within Yenisei-Khatanga and adjacent territories of the Gydan petroleum regions based on models of structure and reconstructed conditions of formation for each of the noted reservoirs and their components – permeable complexes and fluid seals, developed earlier by the authors of this article. Tectonic, lithological-facies and geochemical criteria for assessing the oil-and-gas bearing prospects of reserv

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12

Al-Mahasneh, Mehaysen, Hussam Elddin Al-Khasawneh, Kamel Al-Zboon, Marwan Al-Mahasneh, and Ali Aljarrah. "Water Influx Impact on Oil Production in Hamzeh Oil Reservoir in Northeastern Jordan: Case Study." Energies 16, no. 5 (2023): 2126. http://dx.doi.org/10.3390/en16052126.

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This paper was conducted to delimit the water influx in the Hamzeh oil reservoir, located in northeastern Jordan approximately 150 km east of Amman. Petroleum reservoirs are frequently encompassed by water aquifers that back up the reservoir pressure through water inflow. When the pressure declines in a petroleum reservoir, the water aquifer responds by providing an influx of water. Gradually, the damage is reduced and then eliminated, and more oil is produced from the reservoir. The material balance equation (MBE) is used as the fundamental method for this study, predicting reservoir performa

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Okotie, S., and N. O. Ogbarode. "EVALUATION OF AKPET GT9 GAS CONDENSATE RESERVOIR PERFORMANCE." Open Journal of Engineering Science (ISSN: 2734-2115) 1, no. 1 (2020): 1–13. http://dx.doi.org/10.52417/ojes.v1i1.80.

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To effectively evaluate a gas condensate reservoir performance, the reservoir engineer must have a reasonable amount of knowledge about the reservoir to adequately analyze the reservoir performance and predict future production under various modes of operation. Due to the multiphase flow that exists in the reservoir, characterization of gas condensate reservoirs is often a difficult task with the variation of its overall composition in both space and time during production which complicates well deliverability analysis and the sizing of surface facilities. This study is primarily concern with

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14

Shazly, Ahmed El. "Acid Gas Injection into Petroleum Reservoirs: A Review." Petroleum & Petrochemical Engineering Journal 5, no. 4 (2021): 1–6. http://dx.doi.org/10.23880/ppej-16000280.

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Matrix acidizing using acid gases is an under developed phenomenon in the oil and gas industry. For most petroleum engineers the most common acid gases are carbon dioxide (CO 2 ) and dihydrogen sulfide (H 2 S). CO 2 is mostly injected into oil reservoirs to achieve full/partial miscibility with the crude oil. In the process, CO 2 reacts with formation water to form carbonic acid (a weak acid). Many research papers discuss how carbonic acid reacts with carbonate minerals and causes dissolution. Another popular acid gas in the oil industry is H 2 S. H 2 S is produced as an associated/dissolved g

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15

Dong, Yuwen, Iftikhar Satti, and Xu Chen. "Microfacies and Reservoir Connectivity of Shore Sandbar, Southern Indus Basin, Pakistan." Water 14, no. 10 (2022): 1614. http://dx.doi.org/10.3390/w14101614.

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Shore sand bar reservoirs have attracted much attention as one of the target intervals with the greatest potential for petroleum exploration and development in marine sedimentary basins. Nevertheless, due to lack of effective research methods, it is difficult to analyze the rapid lateral change and heterogeneity in a sand bar reservoir, which has a major impact on the efficient petroleum development that seriously restricts the rolling evaluation and efficient development of sand-bar reservoirs. In this study, based on integrated analysis of cores, thin sections, logging, 3D seismic data, prod

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16

Zhang, Zhaohui, Chuqiao Gao, Yongde Gao, Chunzhen Niu, and Shenglun Ma. "Theoretical Simulation of the Resistivity and Fractured–Cavernous Structures of Carbonate Reservoirs." Processes 12, no. 1 (2023): 43. http://dx.doi.org/10.3390/pr12010043.

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Recently, theoretical modeling based on rock physics has emerged as a pivotal approach to studying the resistivity of complex fractured–cavernous microstructures. In this work, to study the effects of fractured–cavernous structures on carbonate reservoir resistivity, electrical conductivity models were developed based on the effective medium theory and Ohm’s Law, and theoretical simulations were performed to examine how the porosity and resistivity of the rock matrix, the formation water resistivity, and the parameters of the fractured–cavernous microstructure affect the resistivity of rocks s

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17

Jackson, J., I. P. Sweet, and T. G. Powell. "STUDIES ON PETROLEUM GEOLOGY AND GEOCHEMISTRY, MIDDLE PROTEROZOIC, McARTHUR BASIN NORTHERN AUSTRALIA I: PETROLEUM POTENTIAL." APPEA Journal 28, no. 1 (1988): 283. http://dx.doi.org/10.1071/aj87022.

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Mature, rich, potential source beds and adjacent potential reservoir beds exist in the Middle Proterozoic sequence (1400-1800 Ma) of the McArthur Basin. The McArthur and Nathan Groups consist mainly of evaporitic and stromatolitic cherty dolostones interbedded with dolomitic siltstone and shale. They were deposited in interfingering marginal marine, lacustrine and fluvial environments. Lacustrine dolomitic siltstones form potential source beds, while potential reservoirs include vuggy brecciated carbonates associated with penecontemporaneous faulting and rare coarse-grained clastics. In contra

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18

Nimmagadda, Shastri, Neel Mani, Torsten Reiners, and Lincoln C. Wood. "Big Data Guided Unconventional Digital Reservoir Energy Ecosystem and its Knowledge Management." Pacific Asia Journal of the Association for Information Systems 13 (2021): 1–35. http://dx.doi.org/10.17705/1pais.13101.

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Abstract Background: In shale basins, petroleum systems are complex; they hold data sources in Big Data scales. The motivation of research lies with the facts of exploring effective inherent connectivity between unconventional petroleum systems. The connectivity between energy reservoir systems is ambiguous within a distinctive petroleum ecosystem. Heterogeneity and multidimensionality of unstructured data sources are additional challenges, precluding systematic modelling of diverse petroleum systems and their data integration process, including growing demand for storage systems. The research

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19

Saadatinejad, M. R., and H. Hassani. "Application of wavelet transform for evaluation of hydrocarbon reservoirs: example from Iranian oil fields in the north of the Persian Gulf." Nonlinear Processes in Geophysics 20, no. 2 (2013): 231–38. http://dx.doi.org/10.5194/npg-20-231-2013.

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Abstract. The Persian Gulf and its surrounding area are some of the biggest basins and have a very important role in producing huge amounts of hydrocarbon, and this potential was evaluated in order to explore the target for geoscientists and petroleum engineers. Wavelet transform is a useful and applicable technique to reveal frequency contents of various signals in different branches of science and especially in petroleum studies. We applied two major capacities of continuous mode of wavelet transform in seismic investigations. These investigations were operated to detect reservoir geological

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20

Hao, Hui Zhi, and Li Juan Tan. "The Characteristic of Oil and Gas Accumulation and Main Factors of Reservoir Enrichment in SZ36-1 Region." Applied Mechanics and Materials 737 (March 2015): 859–62. http://dx.doi.org/10.4028/www.scientific.net/amm.737.859.

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The hydrocarbon reservoirs which have been found in SZ36-1 region are located in Liaoxi low uplift and dominated by structural traps. The principle source rock is the first and the third member of the Neogen Shahejie Formation and the main reservoir type is delta sand body which mainly located in the second member of Shahejie Formation. Oil reservoirs are mostly in normal pressure and are possess characteristic of late hydrocarbon accumulation. Hydrocarbon accumulation is mainly controlled by fault,reservoir-cap rock combination, and petroleum migration pathways. Lateral distribution of hydroc

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21

Langaas, Kare, Knut I. Nilsen, and Svein M. Skjaeveland. "Tidal Pressure Response and Surveillance of Water Encroachment." SPE Reservoir Evaluation & Engineering 9, no. 04 (2006): 335–44. http://dx.doi.org/10.2118/95763-pa.

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Summary A review of the tidal response in petroleum reservoirs is given. Tidal response is caused by periodic changes in overburden stress induced by the ocean tide; the "tidal efficiency factor" is derived by two different approaches and is in line with a recent well test in the Ormen Lange gas field. For small geomechanical pertubations like the tidal effect, we show that a simplified coupling of geomechanics and fluid flow is possible. The coupling is easy to implement in a standard reservoir simulator by introducing a porosity varying in phase with the tide. Simulations show very good agre

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Troup, Alison, and Behnam Talebi. "Adavale Basin petroleum plays." APPEA Journal 59, no. 2 (2019): 958. http://dx.doi.org/10.1071/aj18083.

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The Devonian Adavale Basin system is an under-explored, frontier petroleum basin in south-west Queensland. It has a confirmed petroleum system with production from the Gilmore gas field. The age, marine depositional environments and high carbonate content suggest the basin may have unconventional petroleum potential, and there has been renewed interest from industry in evaluating the basin. In support of this, the Queensland Department of Natural Resources, Mines and Energy has examined the source rock properties of the Bury Limestone and Log Creek Formation and has commissioned an update to t

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23

Soliman Hunter, Tina. "Role of Underground Carbon Storage to Assist Reaching Net Zero by 2050: Perspectives on Petroleum Reservoirs." International Journal of Petroleum Technology 11 (March 27, 2024): 1–15. http://dx.doi.org/10.15377/2409-787x.2024.11.1.

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This article focuses on the critical role of sedimentary basins in underground carbon storage. Focusing on both depleted petroleum reservoirs, as well as sedimentary reservoirs in the field’s petroleum stratigraphy (associated sedimentary reservoirs), it highlights the importance of complete CO2 storage in saline aquifers associated with petroleum reservoirs. This paper provides a novel approach to the understanding of underground carbon sequestration (UCS) by combining the examination of target reservoirs and regulation of activities in these reservoirs. By combining this consideration of phy

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Chapman, R. E. "GEOLOGICAL REASONING FOR THE PETROLEUM SOURCE ROCKS OF KNOWN FIELDS." APPEA Journal 26, no. 1 (1986): 132. http://dx.doi.org/10.1071/aj85014.

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Geological reasoning for the petroleum source-migration-accumulation relationships centres around petroleum composition and its variability, water composition and its variability, and stratigraphy. For example, a field with several pools of petroleum of different compositions is likely to have been sourced from several distinct source rocks that are stratigraphically associated with the reservoir rocks. If water compositions are also variable, the conclusion is reinforced. A field with several pools of petroleum of similar quality was sourced either from similar source rocks that are stratigra

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Tingate, Peter, Monica Campi, Geoffrey O'Brien, et al. "Understanding the plumbing of the Gippsland Basin: new results on fluid migration and reservoir quality." APPEA Journal 51, no. 2 (2011): 693. http://dx.doi.org/10.1071/aj10073.

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Understanding the CO2 storage potential and petroleum prospectivity of the Gippsland Basin are critical to managing the resources of this region. Key controls on determining the prospectivity for CO2 storage and petroleum include understanding the fluid migration history and reservoir characteristics in the basin. Gippsland Basin hydrology, reservoir characteristics and petroleum systems are being studied to better understand how CO2 can be safely stored in the subsurface. Hydrocarbon migration pathways have been delineated using petroleum systems modelling. The latest hydrocarbon charge histo

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26

Li, Qiangyu, Kangliang Guo, Xinchen Gao, Shuangshuang Zhang, Yuhang Jin, and Jiakang Liu. "Productivity Prediction Model of Tight Oil Reservoir Based on Particle Swarm Optimization–Back Propagation Neural Network." Processes 12, no. 9 (2024): 1890. http://dx.doi.org/10.3390/pr12091890.

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Single-well productivity is a crucial metric for assessing the effectiveness of petroleum reservoir development. The accurate prediction of productivity is essential for achieving the efficient and economical development of oil–gas reservoirs. Traditional productivity prediction methods (empirical formulae and numerical simulation) are limited to specific reservoir types. There are few influencing factors, and a large number of ideal assumptions are made for the assumed conditions when predicting productivity. The application scenario is ideal. However, in tight oil reservoirs, numerous factor

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27

Li, Jiali. "Reservoir Development by Waterflooding and Reservoir Performance Analysis." E3S Web of Conferences 329 (2021): 01066. http://dx.doi.org/10.1051/e3sconf/202132901066.

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With the rapid development of China's society and economy, relevant industries get good development opportunities, and the demand for oil is increasing. The oil production in the oilfield is increasing day by day. At present, most oilfields gradually enter the middle and late stage of water injection exploitation, which increases the exploitation difficulty and reduces the exploitation amount. In this paper, a comprehensive analysis of waterflooding reservoirs and reservoir performance is made to promote better and faster development of petroleum industry.

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Worthington, Paul Francis. "Petrophysical Type Curves for Identifying the Electrical Character of Petroleum Reservoirs." SPE Reservoir Evaluation & Engineering 10, no. 06 (2007): 711–29. http://dx.doi.org/10.2118/96718-pa.

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Summary A user-friendly type chart has been constructed as an aid to the evaluation of water saturation from well logs. It provides a basis for the inter-reservoir comparison of electrical character in terms of adherence to, or departures from, Archie conditions in the presence of significant shaliness and/or low formation-water salinity. Therefore, it constitutes an analog facility. The deliverables include reservoir classification to guide well-log analysis, a protocol for optimizing the acquisition of special core data in support of log analysis, and reservoir characterization in terms of a

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Juell, Aleksander, Curtis H. Whitson, and Mohammad Faizul Hoda. "Model-Based Integration and Optimization—Gas-Cycling Benchmark." SPE Journal 15, no. 02 (2010): 646–57. http://dx.doi.org/10.2118/121252-pa.

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Summary A benchmark for computational integration of petroleum operations has been constructed. The benchmark consists of two gas/ condensate reservoirs producing to a common process facility. A fraction of the processed gas is distributed between the two reservoirs for gas injection. Total project economics is calculated from the produced streams and process-related costs. This benchmark may be used to compare different computational integration frameworks and optimization strategies. Even though this benchmark aims to integrate all parts of a petroleum operation, from upstream to downstream,

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30

Shi, Bao Hong, Juan Wang, and Yan Zhang. "Analysis on Basic Conditions and Main Control Factors of Accumulation in Eastern Area of Yishan Slope of Ordos Basin." Advanced Materials Research 524-527 (May 2012): 10–15. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.10.

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The group of reservoir and cap-rock in Chang4+5 and Chang6 has good basic conditions of accumulation in eastern area of Yishan Slope of Ordos Basin, because it located up the high quality sources rocks (Chang7) and had a lot of hydrocarbon migrated from western areas. The reservoirs were the sand bodies formed in the distributary channels of delta plain and subaqueous distributary channels of delta front. The cap-rocks were the mudstones and compacted siltites formed in the floodplain and interdistributary areas.They composed lithologic traps. The types of petroleum reservoirs belong to lithol

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31

Hofmann, Meil, Sudad Al-Obaidi, and Wang Chang. "Evaluating the efficacy of water alternating gas injection technique in the upper jurassic hydrocarbon reservoirs, considering saturation pressure." Natural Science and Advanced Technology Education 33, no. 3-4 (2024): 237–50. http://dx.doi.org/10.53656/nat2024-3-4.02.

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A tertiary method of enhanced oil recovery (EOR) based on the watergas alternating injection process (WG) is examined in this article based on the ratio between saturation pressure and reservoir pressure. A hydrodynamic simulation of the WAG process was carried out using TEMPEST MORE software (version 7,1). Many hydrocarbon fields worldwide are currently experiencing declining production rates. However, by utilizing advanced technologies like alternate injection of water and associated petroleum gas, the final oil recovery factor (RF) can be significantly increased. To ensure successful water

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Curtis, A. A., J. F. McCarthy, and C. Balnaves. "THE IMPACT OF INTEGRATED RESERVOIR CHARACTERISATION ON THE BUSINESS PERFORMANCE OF THE MODERN PETROLEUM COMPANY." APPEA Journal 37, no. 1 (1997): 105. http://dx.doi.org/10.1071/aj96006.

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One emerging technology that has the capacity to significantly improve the way the petroleum industry undertakes its business is reservoir characterisation. Compelling business drivers for the adoption of reservoir characterisation by petroleum companies exist, including the reduction of project risk, the optimisation of reservoir performance, and the improvement of work practices, all of which can lead to far shorter project cycle times and better financial performance. Integrated Reservoir Characterisation has been successfully applied by one petroleum company following the implementation of

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Gao, P. K., G. Q. Li, H. M. Tian, Y. S. Wang, H. W. Sun, and T. Ma. "Differences in microbial community composition between injection and production water samples of water flooding petroleum reservoirs." Biogeosciences 12, no. 11 (2015): 3403–14. http://dx.doi.org/10.5194/bg-12-3403-2015.

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Abstract. Microbial communities in injected water are expected to have significant influence on those of reservoir strata in long-term water flooding petroleum reservoirs. To investigate the similarities and differences in microbial communities in injected water and reservoir strata, high-throughput sequencing of microbial partial 16S rRNA of the water samples collected from the wellhead and downhole of injection wells, and from production wells in a homogeneous sandstone reservoir and a heterogeneous conglomerate reservoir were performed. The results indicate that a small number of microbial

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Schiozer, Denis José, Antonio Alberto de Souza dos Santos, Susana Margarida de Graça Santos, and João Carlos von Hohendorff Filho. "Model-based decision analysis applied to petroleum field development and management." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 74 (2019): 46. http://dx.doi.org/10.2516/ogst/2019019.

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This work describes a new methodology for integrated decision analysis in the development and management of petroleum fields considering reservoir simulation, risk analysis, history matching, uncertainty reduction, representative models, and production strategy selection under uncertainty. Based on the concept of closed-loop reservoir management, we establish 12 steps to assist engineers in model updating and production optimization under uncertainty. The methodology is applied to UNISIM-I-D, a benchmark case based on the Namorado field in the Campos Basin, Brazil. The results show that the me

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Cheng, Hanlie, Peng Ma, Guofeng Dong, Shun Zhang, Jianfei Wei, and Qiang Qin. "Characteristics of Carboniferous Volcanic Reservoirs in Beisantai Oilfield, Junggar Basin." Mathematical Problems in Engineering 2022 (April 25, 2022): 1–10. http://dx.doi.org/10.1155/2022/7800630.

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In recent years, petroleum exploration in the Carboniferous volcanic rock reservoirs in the Junggar Basin has been the focus of important petroleum energy development in western China. The lithologic identification of volcanic rock reservoirs seriously restricts the accuracy of reservoir prediction and affects the success rate of oil exploration. Different types of volcanic rocks have different petrological characteristics and mineral assemblages, especially affected by the depositional environment. The volcanic rocks in different regions have their own uniqueness. This paper takes the Carboni

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Cheng, Hanlie, Peng Ma, Guofeng Dong, Shun Zhang, Jianfei Wei, and Qiang Qin. "Characteristics of Carboniferous Volcanic Reservoirs in Beisantai Oilfield, Junggar Basin." Mathematical Problems in Engineering 2022 (April 25, 2022): 1–10. http://dx.doi.org/10.1155/2022/7800630.

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In recent years, petroleum exploration in the Carboniferous volcanic rock reservoirs in the Junggar Basin has been the focus of important petroleum energy development in western China. The lithologic identification of volcanic rock reservoirs seriously restricts the accuracy of reservoir prediction and affects the success rate of oil exploration. Different types of volcanic rocks have different petrological characteristics and mineral assemblages, especially affected by the depositional environment. The volcanic rocks in different regions have their own uniqueness. This paper takes the Carboni

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Wang, Yang, Yongqiang Yang, Jiaqiang Luo, and Bateer Chen. "Petroleum Resource Exploration System: As the Dongying Depression, Bohai Bay Basin, China." E3S Web of Conferences 299 (2021): 03006. http://dx.doi.org/10.1051/e3sconf/202129903006.

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Bohai Bay Basin is a hot area for research marine petroleum. Petroleum System is an important method to study petroleum. However, facing on more complicated middle-high graded petroleum exploration area, formerly elements of the Petroleum System are not enough to cover all factors. Hydrocarbon was controlled by main migration path, additionally the complicated mechanism and controlling factors in a formed oil-gas pool are carefully considered. We put “track down (oil-gas reservoir) by following clues (the main migration path of petroleum)” based on the Dongying Depression data, and drill the b

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Jang, Junbong, William F. Waite, and Laura A. Stern. "Gas hydrate petroleum systems: What constitutes the “seal”?" Interpretation 8, no. 2 (2020): T231—T248. http://dx.doi.org/10.1190/int-2019-0026.1.

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The gas hydrate petroleum system (GHPS) approach, which has been used to characterize gas hydrates in nature, uses three distinct components: a methane source, a methane migration pathway, and a reservoir that not only contains gas hydrate, but also acts as a seal to prevent methane loss. Unlike GHPS, a traditional petroleum system (PS) approach further distinguishes between the reservoir, a unit with generally coarser sediment grains, and a separate overlying seal unit with generally finer sediment grains. Adopting this traditional PS distinction in the GHPS approach facilitates assessments o

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Yi, Ziliang, and Jun Yao. "Development of GIS-based framework for reservoir data management and quality evaluation." Journal of Physics: Conference Series 2834, no. 1 (2024): 012192. http://dx.doi.org/10.1088/1742-6596/2834/1/012192.

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Abstract Accurately measuring and understanding reservoirs is critical for ensuring successful reservoir development, reservoir development evaluation have become an increasingly important issue in reservoir development engineering and present many challenges, particularly when attempting to integrate and visualize multiple types of data. This paper presents the methodologies, techniques and integrated services adopted for the design and implementation of A quantitative oil and gas reservoir data management and evaluation system. The system is an integrated application based on petroleum geolo

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Ivakhnenko, Oleksandr P., and David K. Potter. "Magnetic susceptibility of petroleum reservoir fluids." Physics and Chemistry of the Earth, Parts A/B/C 29, no. 13-14 (2004): 899–907. http://dx.doi.org/10.1016/j.pce.2004.06.001.

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Hirasaki, George J., Sho-Wei Lo, and Ying Zhang. "NMR properties of petroleum reservoir fluids." Magnetic Resonance Imaging 21, no. 3-4 (2003): 269–77. http://dx.doi.org/10.1016/s0730-725x(03)00135-8.

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Dusseault, Maurice B. "Geomechanical challenges in petroleum reservoir exploitation." KSCE Journal of Civil Engineering 15, no. 4 (2011): 669–78. http://dx.doi.org/10.1007/s12205-011-0007-5.

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Stevenson, M. D., M. Kagan, and W. V. Pinczewski. "Computational methods in petroleum reservoir simulation." Computers & Fluids 19, no. 1 (1991): 1–19. http://dx.doi.org/10.1016/0045-7930(91)90003-z.

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Yin, Shunde, Maurice B. Dusseault, and Leo Rothenburg. "Thermal reservoir modeling in petroleum geomechanics." International Journal for Numerical and Analytical Methods in Geomechanics 33, no. 4 (2009): 449–85. http://dx.doi.org/10.1002/nag.723.

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Lieu, V. T., S. G. Miller, and S. Miller. "A Laboratory Study of Chemical Reactions With Reservoir Sand in the Recovery of Petroleum by Alkaline Flooding." Society of Petroleum Engineers Journal 25, no. 04 (1985): 587–93. http://dx.doi.org/10.2118/12561-pa.

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Abstract This paper presents the results of a study of the chemical reactions between alkaline chemical solutions and petroleum reservoir sand material. Long Terms tudies were made of alkaline solution flow through reservoir sandpacks. Analyses were conducted to determine the chemical compositions of the effluents. The results obtained are related to the mineral content of the reservoirs and material. Individual chemical reactions of various minerals are discussed. It appears that there is an important initial combination of rapid reversible adsorption and chemical reactions followed by slower

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Boreham, C. J., and R. E. Summons. "NEW INSIGHTS INTO THE ACTIVE PETROLEUM SYSTEMS IN THE COOPER AND EROMANGA BASINS, AUSTRALIA." APPEA Journal 39, no. 1 (1999): 263. http://dx.doi.org/10.1071/aj98016.

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This paper presents geochemical data—gas chromatography, saturated and aromatic biomarkers, carbon isotopes of bulk fractions and individual n-alkanes—for oils and potential source rocks in the Cooper and Eromanga basins, which show clear evidence for different source-reservoir couplets. The main couplets involve Cooper Basin source and reservoir and Cooper Basin source and Eromanga Basin reservoir. A subordinate couplet involving Eromanga Basin source and Eromanga Basin reservoir is also identified, together with minor inputs from pre-Permian source rocks to reservoirs of the Cooper and Eroma

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Kuk, Edyta, Jerzy Stopa, Michał Kuk, Damian Janiga, and Paweł Wojnarowski. "Petroleum Reservoir Control Optimization with the Use of the Auto-Adaptive Decision Trees." Energies 14, no. 18 (2021): 5702. http://dx.doi.org/10.3390/en14185702.

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The global increase in energy demand and the decreasing number of newly discovered hydrocarbon reservoirs caused by the relatively low oil price means that it is crucial to exploit existing reservoirs as efficiently as possible. Optimization of the reservoir control may increase the technical and economic efficiency of the production. In this paper, a novel algorithm that automatically determines the intelligent control maximizing the NPV of a given production process was developed. The idea is to build an auto-adaptive parameterized decision tree that replaces the arbitrarily selected limit v

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Piazza, Ralph, Alexandre Vieira, Luiz Alexandre Sacorague, et al. "Innovative Formation Tester Sampling Procedures for Carbon Dioxide and Other Reactive Components." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 62, no. 1 (2021): 65–72. http://dx.doi.org/10.30632/pjv62n1-2021a4.

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Three questions must be answered to optimize any openhole sampling program. These questions are where to sample, when to sample, and how to sample. Samples must be acquired from the right locations in order to answer the critical questions posed by the asset evaluation and production teams. Samples must be obtained at the right time to minimize contamination while using valuable rig time efficiently. Samples must be taken in a manner that provides the laboratory with the most representative analysis of the subsurface reservoir fluid. Carbon dioxide is a corrosive acidic gas component often fou

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Fang, Wenchao, Xuejie Qin, Chuanxi Liu, et al. "Quantitative Evaluation of Well Performance Affected by Fracture Density and Fracture Connectivity in Fractured Tight Reservoirs." Geofluids 2022 (April 5, 2022): 1–14. http://dx.doi.org/10.1155/2022/2805348.

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Understanding the relationship between petroleum recovery and characteristics of hydraulic fracture network is a key component of economic development of tight reservoirs. Owing to the limitations inherent in current reservoir simulators, optimization of fracture network has been simply focused on the parameters of fracture conductivity, fracture number, aperture, and so on. Deeper insight into the effect of decisive parameters, such as fracture density and fracture connectivity on the well production in tight reservoirs, is now required to maximize the petroleum recovery. In this work, a newl

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He, Zhiliang, Qian Ding, Yujin Wo, Juntao Zhang, Ming Fan, and Xiaojuan Yue. "Experiment of Carbonate Dissolution: Implication for High Quality Carbonate Reservoir Formation in Deep and Ultradeep Basins." Geofluids 2017 (2017): 1–8. http://dx.doi.org/10.1155/2017/8439259.

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As the most frontiers in petroleum geology, the study of dissolution-based rock formation in deep carbonate reservoirs provides insight into pore development mechanism of petroleum reservoir space, while predicting reservoir distribution in deep-ultradeep layers. In this study, we conducted dissolution-precipitation experiments simulating surface to deep burial environments (open and semiopen systems). The effects of temperature, pressure, and dissolved ions on carbonate dissolution-precipitation were investigated under high temperature and pressure (~200°C; ~70 Mpa) with a series of petrograp

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