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Articoli di riviste sul tema "Hydrocarbon reservoirs"

Autore: Grafiati

Pubblicato: 4 giugno 2021

Ultima modifica: 1 agosto 2024

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1

Lü, Xiuxiang, Weiwei Jiao, Xinyuan Zhou, Jianjiao Li, Hongfeng Yu, and Ning Yang. "Paleozoic Carbonate Hydrocarbon Accumulation Zones in Tazhong Uplift, Tarim Basin, Western China." Energy Exploration & Exploitation 27, no. 2 (April 2009): 69–90. http://dx.doi.org/10.1260/0144-5987.27.2.69.

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Diverse types of marine carbonate reservoirs have been discovered in the Tazhong Uplift, Tarim Basin, and late alteration of such reservoirs is obvious. The marine source rocks of the Cambrian-lower Ordovician and the middle-upper Ordovician provided abundant oil and gas for hydrocarbon accumulation. The hydrocarbons filled various reservoirs in multiple stages to form different types of reservoirs from late Caledonian to early Hercynian, from late Hercynian to early Indosininan and from late Yanshanian to Himalayan. All these events greatly complicated hydrocarbon accumulation. An analysis of

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2

Li, Xiaoshan, Hong Pan, Yuxiao Wu, Guanxing Luo, Junqiang Song, Liu Yang, Kaifang Gu, et al. "Main Control Factors and Hydrocarbon Accumulation Model of Volcanic Oil Reservoirs with Complex Oil–Water Relationships: A Case Study of the Carboniferous in the Chepaizi Uplift, the Junggar Basin, China." Minerals 12, no. 11 (October 26, 2022): 1357. http://dx.doi.org/10.3390/min12111357.

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In order to study the main control factors of volcanic reservoirs with complex oil–water relationships, the Carboniferous in the Chepaizi Uplift of the Junggar Basin was taken as an example and the lithofacies characteristics, main control factors, and hydrocarbon accumulation model of volcanic reservoirs were investigated by combining the petroleum geology with field testing (data of core analysis, well logging, formation testing, and production testing). The results show that the Carboniferous in the Chepaizi Uplift experienced three stages of volcanic activities and developed seven volcanic

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3

Chen, Junqing, Xiongqi Pang, and Zhenxue Jiang. "Controlling factors and genesis of hydrocarbons with complex phase state in the Upper Ordovician of the Tazhong Area, Tarim Basin, China." Canadian Journal of Earth Sciences 52, no. 10 (October 2015): 880–92. http://dx.doi.org/10.1139/cjes-2014-0209.

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Seven hydrocarbon reservoirs have been discovered to date in the Upper Ordovician of the Tazhong Area, a region in which hydrocarbon phase distribution is complex. In the present study, the genesis and controlling factors of the hydrocarbons with complex phase in the Tazhong Area were investigated on the basis of the geological and geochemical conditions required for the formation and distribution of hydrocarbon reservoirs, integrated with the source rock geochemistry, natural gas and oil properties, and oil and gas reservoir fluid tests PVT (i.e., pressure, volume, and temperature tests). The

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4

Lerche, Ian. "Hydrocarbon Flow-up Intersecting Faults: Leakage/Production and Bypass Considerations." Energy Exploration & Exploitation 23, no. 4 (August 2005): 225–43. http://dx.doi.org/10.1260/014459805775219157.

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This article considers flow of hydrocarbons up a master fault that bifurcates and allows the hydrocarbons to enter or bypass reservoirs on either side of the bifurcated fault. In addition, leakage (or production) from each reservoir is allowed with a finite time span for the leakage. The rates of leakage from the two reservoirs are also allowed to be different so that the reservoirs either may fill, with concomitant bypass of excess hydrocarbons, or may be drained so rapidly by the leakage that they fill only partially. The timing of the leakage in respect of the timing of hydrocarbon fill is

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5

Ojo, Odunayo Tope. "Petrophysical and Geomechanical Analysis to Delineating Reservoirs in the Miocene Niger Delta Region of Nigeria." Geoinformatica Polonica 22 (December 1, 2023): 105–21. http://dx.doi.org/10.4467/21995923gp.23.009.18608.

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The application of various petrophysical and elastic metrics has advanced reservoir characterization and provided critical geological formation information. Porosity declines with depth, according to sonic, neutron, and density logs. Lithology, pressure, and hydrocarbons all contribute to this. Formation resistivity and fluid saturation are used to identify hydrocarbon-bearing zones. Because oil and gas are non-conductive, hydrocarbon-containing rocks are more resistant than water. In lithological categorization, gamma logs and the Vp/Vs ratio have helped classify reservoirs as Agbada Formatio

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6

Peng, Biao, Lulu Zhang, Jianfeng Li, Tiantian Chang, and Zheng Zhang. "Multi-Type Hydrocarbon Accumulation Mechanism in the Hari Sag, Yingen Ejinaqi Basin, China." Energies 15, no. 11 (May 27, 2022): 3968. http://dx.doi.org/10.3390/en15113968.

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With the successful development of unconventional hydrocarbons, the production of unconventional hydrocarbons has increased rapidly. However, a single conventional or unconventional model is not suitable for the mechanism of hydrocarbon accumulation in a given basin or sag. Based on data from drilling, logging, and geophysical analysis, the hydrocarbon accumulation mechanism in the Hari sag in the Yingen-Ejinaqi basin, China, was analyzed. There are three sets of source rocks in the Hari sag: the K1y source rocks were evaluated as having excellent source rock potential with low thermal maturit

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7

Mujakperuo, B. J. O., and O. J. Airen. "Pressure volume temperature evaluation of Sapele Field, Niger Delta, Southern Nigeria." Environmental Technology and Science Journal 15, no. 1 (June 24, 2024): 168–75. http://dx.doi.org/10.4314/etsj.v15i1.17.

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Sapele field is a large, brown field with complex subsurface structure that has led to heavy compartmentalization of its reservoirs which has also resulted to low reservoir pressure in some parts of the field leading to low production output. Reservoirs were delineated at various depth, some at near surface area (Benin formation) while others at greater depth (Agbada formation), hence the field was further subdivided into two (Sapele Shallow and Sapele Deep) due to its structural complexity. Pressure Volume Temperature (PVT) laboratory analysis on different wells was available for this study a

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8

Rashid, Muhammad, Miao Luo, Umar Ashraf, Wakeel Hussain, Nafees Ali, Nosheen Rahman, Sartaj Hussain, Dmitriy A. Martyushev, Hung Vo Thanh, and Aqsa Anees. "Reservoir Quality Prediction of Gas-Bearing Carbonate Sediments in the Qadirpur Field: Insights from Advanced Machine Learning Approaches of SOM and Cluster Analysis." Minerals 13, no. 1 (December 24, 2022): 29. http://dx.doi.org/10.3390/min13010029.

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The detailed reservoir characterization was examined for the Central Indus Basin (CIB), Pakistan, across Qadirpur Field Eocene rock units. Various petrophysical parameters were analyzed with the integration of various cross-plots, complex water saturation, shale volume, effective porosity, total porosity, hydrocarbon saturation, neutron porosity and sonic concepts, gas effects, and lithology. In total, 8–14% of high effective porosity and 45–62% of hydrocarbon saturation are superbly found in the reservoirs of the Eocene. The Sui Upper Limestone is one of the poorest reservoirs among all these

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9

Zhao, Shuangfeng, Wen Chen, Zhenhong Wang, Ting Li, Hongxing Wei, and Yu Ye. "Fluid geochemistry of the Jurassic Ahe Formation and implications for reservoir formation in the Dibei area, Tarim Basin, northwest China." Energy Exploration & Exploitation 36, no. 4 (February 22, 2018): 801–19. http://dx.doi.org/10.1177/0144598718759560.

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The condensate gas reservoirs of the Jurassic Ahe Formation in the Dibei area of the Tarim Basin, northwest China are typical tight sandstone gas reservoirs and contain abundant resources. However, the hydrocarbon sources and reservoir accumulation mechanism remain debated. Here the distribution and geochemistry of fluids in the Ahe gas reservoirs are used to investigate the formation of the hydrocarbon reservoirs, including the history of hydrocarbon generation, trap development, and reservoir evolution. Carbon isotopic analyses show that the oil and natural gas of the Ahe Formation originate

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10

Lerche, Ian. "Hydrocarbon Flow along Intersecting Faults." Energy Exploration & Exploitation 23, no. 2 (April 2005): 107–23. http://dx.doi.org/10.1260/0144598054529996.

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This paper is concerned with the channeling of hydrocarbon flow up a master fault and the diversion of the flow to the left or right at the intersection of the master fault with a second fault. In particular, when reservoirs of different capacities can exist on the master fault and the secondary fault, the question of the retention efficiency of the reservoirs to the hydrocarbon flow is of interest. In addition, given the customary lack of sharp knowledge of the hydrocarbon petroleum system before drilling, the influence of uncertainties in the flow and reservoir properties is discussed in ter

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11

Zhou, Tianqi, Chaodong Wu, Xutong Guan, Jialin Wang, Wen Zhu, and Bo Yuan. "Effect of Diagenetic Evolution and Hydrocarbon Charging on the Reservoir-Forming Process of the Jurassic Tight Sandstone in the Southern Junggar Basin, NW China." Energies 14, no. 23 (November 23, 2021): 7832. http://dx.doi.org/10.3390/en14237832.

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Deeply buried sandstones in the Jurassic, Toutunhe Formation, are a crucial exploration target in the Junggar Basin, NW China, whereas, reservoir-forming process of sandstones in the Toutunhe Formation remain unknown. Focused on the tight sandstone of the Toutunhe Formation, the impacts of diagenesis and hydrocarbon charging on sandstone reservoir-forming process were clarified based on the comprehensive analysis of sedimentary characteristics, petrography, petrophysical characteristics, and fluid inclusion analysis. Three diagenetic facies developed in the Toutunhe sandstone reservoirs, inclu

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12

Sun, Yu, Shi Zhong Ma, Bai Quan Yan, and Chen Chen. "Controlling Factors for Reservoirs Distribution of the Putaohua Oil Layer in the Saozhao Sag." Advanced Materials Research 616-618 (December 2012): 816–20. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.816.

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Types of found reservoirs and its distribution characteristics of Putaohua oil layer in the Sanzhao Sag were analyzed. The controlling factors of hydrocarbon distribution were investigated. Sanzhao Sag is Sag-wide oil-bearing, but its distribution of oil and water is extremely complicated. The reservoir types are mainly fault block reservoirs, low amplitude structure reservoirs, fault-lithologic reservoirs and lithologic reservoirs. The distribution of reservoirs is mainly controlled by three geological factors: first, long-term inherited nose-like structure is predominant direction of petrole

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13

Jumiati, Wiwiek, David Maurich, Andi Wibowo, and Indra Nurdiana. "The Development of Non-Conventional Oil and Gas in Indonesia." Journal of Earth Energy Engineering 9, no. 1 (April 19, 2020): 11–16. http://dx.doi.org/10.25299/jeee.2020.4074.

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Oil and gas fuel from unconventional types of reservoirs was the development of alternative sources in addition to oil and gas fuels from conventional type reservoirs that can be obtained to meet domestic needs. The development of unconventional oil and gas reservoirs has developed rapidly outside Indonesia, such as in North America and Canada. One type of unconventional oil and gas reservoir was obtained from shale rock reservoirs. Hydrocarbon shale produced from shale formations, both source from rock and reservoir. This unconventional hydrocarbon has a big potential to be utilized. In this

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14

Shi, Wen-rui, Chong Zhang, Shao-yang Yuan, Yu-long Chen, and Lin-qi Zhu. "A Crossplot for Mud Logging Interpretation of Unconventional Gas Shale Reservoirs and its Application." Open Petroleum Engineering Journal 8, no. 1 (August 19, 2015): 265–71. http://dx.doi.org/10.2174/1874834101508010265.

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The drilling time data of gas logging are used to calculate drilling time ratio of the reservoir, and the total hydrocarbon data are used to calculate hydrocarbon contrast coefficient and to establish the drilling time ratio--hydrocarbon contrast coefficient crossplot. The standards of distinguishing the boundaries of hydrocarbon zones, hydrocarbonaceous water layers and dry layers are determined according to the statistics of regional oil testing data. Based on the standards, the crossplot is divided into three areas: hydrocarbon zone, hydrocarbonaceous water layer and dry layer, which are us

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15

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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16

Chen, Mei Tao, Ning Yang, and Shang Ming Yang. "Paleozoic Carbonate Hydrocarbon Accumulation Zones in Tahong Uplift Tarim Basin, Western China." Advanced Materials Research 403-408 (November 2011): 1511–16. http://dx.doi.org/10.4028/www.scientific.net/amr.403-408.1511.

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Analyzing the discovered carbonate reservoirs in the Tazhong area, Tarim Basin indicates that the development of a reservoir is controlled by subarial weathering and freshwater leaching processes, sedimentation, early diagenesis, and alteration by deep fluids. According to the origin and lateral distribution of reservoirs, the hydrocarbon accumulation zones in the Tazhong area are classified into four types: buried hill and palaeoweathering crust, organic buildup reef-bank, dolomite interior, and deep fluid alteration. Different types of carbonate hydrocarbon accumulation zones are distributed

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17

Sun, Zhen, Zhen Yang, Xiaoning He, Cixuan Wan, Gang He, Qiang Ren, Shihu Zhao, Wei Cheng, and Sisi Chen. "Geochemical Characteristics of Formation Water in Carbonate Reservoirs and Its Indication to Hydrocarbon Accumulation." Geofluids 2022 (October 11, 2022): 1–11. http://dx.doi.org/10.1155/2022/6095178.

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The migration path of formation water plays an indispensable role in hydrocarbon accumulation and preservation. The hydrodynamic field controls the content of various ions in formation water and is an important participant in hydrocarbon evolution. Formation water can basically be used to judge the preservation status of oil/gas reservoirs, especially for carbonate reservoirs; the carbonate reservoirs are a typical example in the Gaoqiao area of the Ordos Basin, China. However, it is not easy to evaluate the sealing and integrity of the gas reservoir because hydrocarbon has experienced a multi

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18

Neff, Dennis B. "Incremental pay thickness modeling of hydrocarbon reservoirs." GEOPHYSICS 55, no. 5 (May 1990): 556–66. http://dx.doi.org/10.1190/1.1442867.

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The one-dimensional convolution model or synthetic seismogram provides more information about the seismic waveform expression of hydrocarbon reservoirs when petrophysical data (porosity, shale volume, water saturation, etc.) are systematically integrated into the seismogram generation process. Use of this modeling technique, herein called Incremental Pay Thickness (IPT) modeling, has provided valuable insights concerning the seismic response of several offshore Gulf of Mexico amplitude anomalies. Through integration of the petrophysical data, comparisons between seismic waveform response and e

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19

Zagranovskaya, D. E., S. I. Isaeva, A. P. Vilesov, V. A. Shashel, O. A. Zakharova, E. O. Belyakov, V. Yu Demin, I. L. Kudin, and G. A. Kalmykov. "Structure of continues reservoirs in the Domanik formation and petrophysical interpretation methods." Moscow University Bulletin. Series 4. Geology 1, no. 6 (January 29, 2022): 120–32. http://dx.doi.org/10.33623/0579-9406-2021-6-120-132.

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Properties of unconventional prospective deposits are interconnected by the rocesses of reservoir formation and oil and gas formation. Dispersed dolomite in situ formed during the maturation of TOC from syngenetic magnesium in the rock matrix increases the void space of the rock, thereby forming an unconventional reservoir filled with autochthonous hydrocarbons and oil components. In the process of TOC maturation and hydrocarbon migration, the TOC components are redistributed in the void space, thereby, the released volume of rocks is filled with stationary resinous asphaltene substances, whic

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Ziemelis, Karl. "Hydrocarbon reservoirs." Nature 426, no. 6964 (November 2003): 317. http://dx.doi.org/10.1038/426317a.

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Zhang, Yuanyuan, Zhanli Ren, Youlu Jiang, and Jingdong Liu. "Differential hydrocarbon enrichment in deep Paleogene tight sandstones of the Dongpu Depression in Eastern China." Energy Exploration & Exploitation 39, no. 3 (January 21, 2021): 797–814. http://dx.doi.org/10.1177/0144598720988112.

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To clarify the characteristics and enrichment rules of Paleogene tight sandstone reservoirs inside the rifted-basin of Eastern China, the third member of Shahejie Formation (abbreviated as Es3) in Wendong area of Dongpu Depression is selected as the research object. It not only clarified the geochemical characteristics of oil and natural gas in the Es3 of Wendong area through testing and analysis of crude oil biomarkers, natural gas components and carbon isotopes, etc.; but also compared and explained the types and geneses of oil and gas reservoirs in slope zone and sub-sag zone by matching re

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22

Fu, Siyi, Zhiwei Liao, Anqing Chen, and Hongde Chen. "Reservoir characteristics and multi-stage hydrocarbon accumulation of the Upper Triassic Yanchang Formation in the southwestern Ordos Basin, NW China." Energy Exploration & Exploitation 38, no. 2 (August 19, 2019): 348–71. http://dx.doi.org/10.1177/0144598719870257.

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The Chang-8 and Chang-6 members of the Upper Triassic Yanchang Formation (lower part) are regarded as the main oil producing members of the Ordos Basin. Recently, new hydrocarbon discoveries have been made in the upper part of the Yanchang Formation (e.g., Chang-3) in the southwestern Ordos Basin, implying that this interval also has a good potential for hydrocarbon exploration. However, studies on the origin of the high-quality reservoir, hydrocarbon migration, and accumulation patterns remain insufficient. In this study, integrated petrological, mineralogical, and fluid inclusion tests are e

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23

Finecountry, S. C. P., and S. Inichinbia. "Lithology and Fluid discrimination of Sody field of the Nigerian Delta." Journal of Applied Sciences and Environmental Management 24, no. 8 (September 9, 2020): 1321–27. http://dx.doi.org/10.4314/jasem.v24i8.3.

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The lithology and fluid discrimination of an onshore Sody field, of the Niger Delta was studied using gamma ray, resistivity and density logs from three wells in the field in order to evaluate the field’s reservoir properties. Two reservoir sands (RES 1 and RES 2) were delineated and identified as hydrocarbon bearing reservoirs. The petrophysical parameters calculated include total porosity, water saturation and volume of shale. The results obtained revealed that the average porosity of the reservoir sands, range from 21% to 39%, which is excellent indicator of a good quality reservoir and pro

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24

Liu, Shaojun, Shengxian Zhao, Xuefeng Yang, Jian Zhang, Meixuan Yin, Qi’an Meng, Bo Li, and Ziqiang Xia. "“Tri-in-One” Accumulation Model of Lithologic Reservoirs in Continental Downfaulted Basins: A Case Study of the Lithologic Reservoir of Nantun Formation in Tanan Sag, Mongolia." Processes 11, no. 8 (August 4, 2023): 2352. http://dx.doi.org/10.3390/pr11082352.

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This article analyzes the key controlling factors and hydrocarbon distribution rules of lithologic reservoirs in a continental downfaulted basin according to the structural features, sedimentary evolution, types of sedimentary facies, source rock features, diagenesis evolution, reservoir features, hydrocarbon formation mechanisms, exploration status, and hydrocarbon resource potential. The results show that three major controlling factors (sandbody types, effective source rocks, and effective reservoirs) and one coupled factor (fractures that act as a tie) influence hydrocarbon accumulation in

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Islamov, Shamil, Ravil Islamov, Grigory Shelukhov, Anar Sharifov, Radel Sultanbekov, Rustem Ismakov, Akhtyam Agliullin, and Radmir Ganiev. "Fluid-Loss Control Technology: From Laboratory to Well Field." Processes 12, no. 1 (January 2, 2024): 114. http://dx.doi.org/10.3390/pr12010114.

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Effective fluid-loss control in oil wells is a critical concern for the oil industry, particularly given the substantial reserves situated in carbonate reservoirs globally. The prevalence of such reservoirs is expected to rise with the slow depletion of hydrocarbons, intensifying the need to address challenges related to deteriorating reservoir properties post well-killing operations. This deterioration results in significant annual losses in hydrocarbon production at major oil enterprises, impacting key performance indicators. To tackle this issue, this study focuses on enhancing well-killing

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D., Imikanasua, Tamunobereton-Ari I, and Ngeri A.P. "Determination of Reservoir Quality in Field “D” in Central Niger Delta, Using Well Log Data." Asian Journal of Applied Science and Technology 06, no. 01 (2022): 142–51. http://dx.doi.org/10.38177/ajast.2022.6117.

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Well log data was used in this study to assess reservoir properties of field "D" in the southern area of the Niger Delta. For successful petrophysical evaluation, three hydrocarbon-bearing reservoirs (reservoirs A, B, and C) were identified and correlated. The following metrics were tested to determine reservoir properties: porosity, permeability, shale volume, fluid saturation, and net pay thickness. The calculated reservoir property values indicate high reservoir quality. Porosity readings in well OTIG 2 are almost the same, averaging 20%, but values in wells OTIG 7 and OTIG 9 vary from 14-2

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Junira, Adi, and Andy Setyo Wibowo. "SHALE AS HYDROCARBON RESERVOIRS." Scientific Contributions Oil and Gas 39, no. 2 (October 8, 2018): 71–75. http://dx.doi.org/10.29017/scog.39.2.104.

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Nowadays, shale plays a role as hydrocarbon producing rock. Due to its unusual properties as a reservoir, shale is classified as an unconventional reservoir. Among these properties are the relatively low permeability (0.1 mD or less) and the relatively low porosity (10% or less). The relatively low permeability had been the main obstacle to extracting the hydrocarbon held by shale in the past. Nevertheless, the technologies of horizontal drilling and hydraulic fracturing have proven to be effective in stimulating a liquid flow in low permeability reservoirs such as a shale layer which has enco

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Collen, J. D. "Diagenetic Control of Porosity and Permeability in Pakawau and Kapuni Group Sandstones, Taranaki Basin, New Zealand." Energy Exploration & Exploitation 6, no. 3 (June 1988): 263–80. http://dx.doi.org/10.1177/014459878800600307.

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Porosity and permeability of Cretaceous to Oliogocene Pakawau and Kapuni Group sandstones in Taranaki Basin, New Zealand, have been extensively modified by burial diagenesis. Mechanical compaction and the precipitation of silica, carbonate and authigenic clays have caused marked deterioration of potential and actual reservoirs for hydrocarbons. Other authigenic minerals have had less effect. Secondary reservoir porosity and permeability have developed in significant volumes in sandstones at various places, at depths below about 2.5 km. They have formed by dissolution of detrital grains, authig

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Sun, Xiaoming, Siyuan Cao, Xiao Pan, Xiangyang Hou, Hui Gao, and Jiangbo Li. "Characteristics and prediction of weathered volcanic rock reservoirs: A case study of Carboniferous rocks in Zhongguai paleouplift of Junggar Basin, China." Interpretation 6, no. 2 (May 1, 2018): T431—T447. http://dx.doi.org/10.1190/int-2017-0159.1.

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Volcanic reservoirs have been overlooked for hydrocarbon exploration for a long time. Carboniferous volcanic rocks of the Zhongguai paleouplift contain proven reserves of [Formula: see text]. We have investigated the volcanic reservoirs integrating cores, well, and seismic data, and the proposed volcanic reservoir distribution is controlled by the weathering function, fractures, and lithology. The weathering process makes the originally tight igneous rocks become good-quality reservoirs, and fractures play an important role in connecting different types of pores and act as reservoir space. Iso

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Lawal, Kazeem A., Asekhame U. Yadua, Mathilda I. Ovuru, Oluchukwu M. Okoh, Stella I. Eyitayo, Saka Matemilola, and Olugbenga Olamigoke. "Rapid screening of oil-rim reservoirs for development and management." Journal of Petroleum Exploration and Production Technology 10, no. 3 (December 2, 2019): 1155–68. http://dx.doi.org/10.1007/s13202-019-00810-6.

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AbstractAs an improvement over existing screening techniques, we introduce the relative mobile energy of primary gas-cap to the aquifer (Egw) as a new parameter for characterizing the performance of oil-rim reservoirs. Egw integrates key static and dynamic reservoir properties. To account for the time value of production, the framework allows maximizing the discounted recovery factor (DRF) of oil, gas or total hydrocarbon as the objective function. Employing detailed simulations of different well-defined oil-rim models, DRFs of oil, gas and total hydrocarbons have been correlated against Egw f

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Ayala, Luis F., Turgay Ertekin, and Michael A. Adewumi. "Compositional Modeling of Retrograde Gas-Condensate Reservoirs in Multimechanistic Flow Domains." SPE Journal 11, no. 04 (December 1, 2006): 480–87. http://dx.doi.org/10.2118/94856-pa.

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Summary A multimechanistic flow environment is the result of the combined action of a Darcian flow component (the macroscopic flow of the phase caused by pressure gradients) and a Fickian-like or diffusive flow component (diffusive flow caused by molecular concentration gradients) taking place in a hydrocarbon reservoir. The present work presents the framework needed for the assessment of the impact of multimechanistic flow on systems where complex fluid behavior—such as that of retrograde gas-condensate fluids—requires the implementation of compositional reservoir simulators. Because of the c

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Wang, Ziyi, Zhiqian Gao, Tailiang Fan, Hehang Zhang, Lixin Qi, and Lu Yun. "Hydrocarbon-bearing characteristics of the SB1 strike-slip fault zone in the north of the Shuntuo Low Uplift, Tarim Basin." Petroleum Geoscience 27, no. 1 (July 1, 2020): petgeo2019–144. http://dx.doi.org/10.1144/petgeo2019-144.

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The SB1 strike-slip fault zone, which developed in the north of the Shuntuo Low Uplift of the Tarim Basin, plays an essential role in reservoir formation and hydrocarbon accumulation in deep Ordovician carbonate rocks. In this research, through the analysis of high-quality 3D seismic volumes, outcrop, drilling and production data, the hydrocarbon-bearing characteristics of the SB1 fault are systematically studied. The SB1 fault developed sequentially in the Paleozoic and formed as a result of a three-fold evolution: Middle Caledonian (phase III), Late Caledonian–Early Hercynian and Middle–Late

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Yusubov, N. P., and T. N. Shikhmammadova. "Hydrocarbon system of the South Caspian Depression." Geofizicheskiy Zhurnal 44, no. 3 (August 24, 2022): 87–95. http://dx.doi.org/10.24028/gj.v44i3.261971.

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Actuality. The hydrocarbon generation sources in the South Caspian Basin (SCB) are located at the depth of nine or more kilometers, where the organic-rich Maikop sediments occur. The main oil-and-gas fields here are found in reservoirs of the Productive Strata (Lower Pliocene), bedding at a depth of one or more kilometers. At the same time, the significant role at the process of hydrocarbons migration from the source of their generation to the reservoirs belongs to the tectonic faults (fractures). However, the results of the research according to the latest seismic data carried out in recent y

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34

Tagiyev, M. F., and I. N. Askerov. "Geologic-geochemical and modelling studies of hydrocarbon migration in the South Caspian basin." Azerbaijan Oil Industry, no. 10 (October 15, 2020): 4–15. http://dx.doi.org/10.37474/0365-8554/2020-10-4-15.

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Based on pyrolysis data an overview is given on the generative potential and maturity of individual stratigraphic units in the South Caspian sedimentary cover. Furthermore, the pyrolysis analyses indicate that the Lower Pliocene Productive Series being immature itself is likely to have received hydrocarbon charge from the underlying older strata. The present state of the art in studying hydrocarbon migration and the "source-accumulation" type relationship between source sediments and reservoired oils in the South Caspian basin are touched upon. The views of and geochemical arguments by differe

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35

G.E., Onyishi, Ugwu G.Z., and Onyishi S.E. "Reservoir Characterization of an Onshore Geofield in Niger Delta, Nigeria, using Offset Well Data." African Journal of Environment and Natural Science Research 6, no. 2 (July 16, 2023): 43–50. http://dx.doi.org/10.52589/ajensr-mcjhlepv.

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Three wells (GE_11, G_12 and G_13) in an onshore geofield in the Niger Delta, Nigeria, were used to characterise the reservoirs of the oil field. RokDoc (5.1) and Petrel (2014.1) software were employed for data analysis and characterisation of the reservoirs. A comprehensive petrophysical analysis of each well was carried out in other to ascertain the physical properties such as shale volume, porosity, fluid saturation, net pay thickness and gross pay thickness. The well information was also used to evaluate the lithology and hydrocarbon depth. The hydrocarbon depths in the reservoirs ranged f

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Efemena, O. O., and C. U. Ugwueze. "Hydrocarbon production potential of paralic reservoirs from the Niger Delta basin: Evidence from ichnological studies." Scientia Africana 23, no. 2 (May 14, 2024): 80–87. http://dx.doi.org/10.4314/sa.v23i2.8.

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Abstract (sommario):

Reservoir ichnological study was employed to improve on the inconsistencies and poor interpretation of hydrocarbon-bearing strata within the multipartite maturing terrain of the onshore Niger Delta basin. Ichnofacies characterization revealed two distinctive trace fossil suites that both reflected different feeding behaviours and responses to substrate consistency, which assisted in the high-resolution assessment of facies constituting the paralic reservoirs. Fifteen potential reservoir intervals were subdivided into productive and non-productive as revealed on core slabs as well as well log s

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Chen, Fangwen, Shuangfang Lu, and Xue Ding. "Organoporosity Evaluation of Shale: A Case Study of the Lower Silurian Longmaxi Shale in Southeast Chongqing, China." Scientific World Journal 2014 (2014): 1–9. http://dx.doi.org/10.1155/2014/893520.

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Abstract (sommario):

The organopores play an important role in determining total volume of hydrocarbons in shale gas reservoir. The Lower Silurian Longmaxi Shale in southeast Chongqing was selected as a case to confirm the contribution of organopores (microscale and nanoscale pores within organic matters in shale) formed by hydrocarbon generation to total volume of hydrocarbons in shale gas reservoir. Using the material balance principle combined with chemical kinetics methods, an evaluation model of organoporosity for shale gas reservoirs was established. The results indicate that there are four important model p

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Maju-Oyovwikowhe, E. G., and E. J. Ighodaro. "Petrophysical properties and volume estimation of hydrocarbon resources in x field, onshore niger delta: A reservoir characterization study." Scientia Africana 22, no. 1 (May 31, 2023): 151–74. http://dx.doi.org/10.4314/sa.v22i1.14.

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Abstract (sommario):

A reservoir characterization study was conducted on three wells located in X Field, situated in the Onshore region of the Niger Delta. A suite of conventional digital well logs was utilized to identify hydrocarbon-bearing reservoirs, determine reservoir petrophysical parameters, and infer the depositional environment. The study delineated four hydrocarbon-bearing reservoirs, labeled A, B, C, and D, with porosity estimates ranging from 25% to 27%, and permeability values varying from 1863.22md to 2759.78md. These results suggest that the reservoirs have good storage capacity and permit free flo

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39

Enamekere Umoh, Ekaete, Peace Oluwaseyi Agbaje, and Joseph Oluwaseun Akinade. "Hydrocarbon Formation Evaluation Using Well Log Data Of Well Tmg-02, Opolo Field, Niger Delta." Global Journal of Pure and Applied Sciences 29, no. 2 (September 29, 2023): 165–74. http://dx.doi.org/10.4314/gjpas.v29i2.7.

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Well TMG-02 with the depth interval of 5058.77 to 9389.43ft of Opolo field located in the Niger delta was assessed for hydrocarbon using suite of geophysical well logs. Suite includes gamma ray (GR), formation density (RHOB), neutron porosity (NPHI), and resistivity logs. The analysis was carried out to estimate the field’s hydrocarbon prospect by identifying hydrocarbon bearing reservoirs and their properties. The quantitative and qualitative results, identified thicker units of sand than shale lithology, three reservoirs A, B, C within the depth ranges from 5058.77ft to 9389.43ft, capable of

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40

Malvić, Tomislav, Josip Ivšinović, Josipa Velić, Jasenka Sremac, and Uroš Barudžija. "Increasing Efficiency of Field Water Re-Injection during Water-Flooding in Mature Hydrocarbon Reservoirs: A Case Study from the Sava Depression, Northern Croatia." Sustainability 12, no. 3 (January 21, 2020): 786. http://dx.doi.org/10.3390/su12030786.

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Abstract (sommario):

The authors analyse the process of water re-injection in the hydrocarbon reservoirs/fields in the Upper Miocene sandstone reservoirs, located in the western part of the Sava Depression (Croatia). Namely, this is the “A” field with “L” reservoir that currently produces hydrocarbons using a secondary recovery method, i.e., water injection (in fact, re-injection of the field waters). Three regional reservoir variables were analysed: Porosity, permeability and injected water volumes. The quantity of data was small for porosity reservoir “L” and included 25 points; for permeability and injected vol

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41

Bawahab, Mohammed, and Dmour Hazim. "Performance Analysis of a Water-Drive Oil Reservoir: An Oilfield Case Study." Geosciences and Engineering 11, no. 1 (October 27, 2023): 117–32. http://dx.doi.org/10.33030/geosciences.2023.01.010.

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Abstract (sommario):

One of the primary responsibilities of a reservoir engineer is to evaluate the performance of hydrocarbon reservoirs to estimate the original hydrocarbons in place, reserves, ultimate oil/gas recovery factor. This responsibility becomes complicated in the case of water-drive reservoirs due to the high uncertainty associated with aquifer properties, including rock properties and aquifer geometry. This paper presents a new method to find the optimum aquifer model based on the root mean square error (RMSE) values by using MBAL software. The study investigated the transmissibility between the X, Y

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42

Pitakbunkate, T., P. B. Balbuena, G. J. Moridis, and T. A. Blasingame. "Effect of Confinement on Pressure/Volume/Temperature Properties of Hydrocarbons in Shale Reservoirs." SPE Journal 21, no. 02 (April 14, 2016): 621–34. http://dx.doi.org/10.2118/170685-pa.

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Abstract (sommario):

Summary Shale reservoirs play an important role as a future energy resource of the United States. Numerous studies were performed to describe the storage and transport of hydrocarbons through ultrasmall pores in the shale reservoirs. Most of these studies were developed by modifying techniques used for conventional reservoirs. The common pore-size distribution of the shale reservoirs is approximately 1 to 20 nm and in such confined spaces that the interactions between the wall of the container (i.e., the shale and kerogen) and the contained fluids (i.e., the hydrocarbon fluids and water) may e

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43

Alharthy, Najeeb S., Tadesse W. Teklu, Thanh N. Nguyen, Hossein Kazemi, and Ramona M. Graves. "Nanopore Compositional Modeling in Unconventional Shale Reservoirs." SPE Reservoir Evaluation & Engineering 19, no. 03 (May 7, 2016): 415–28. http://dx.doi.org/10.2118/166306-pa.

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Abstract (sommario):

Summary Understanding the mechanism of multicomponent mass transport in the nanopores of unconventional reservoirs, such as Eagle Ford, Niobrara, Woodford, and Bakken, is of great interest because it influences long-term economic development of such reservoirs. Thus, we began to examine the phase behavior and flow characteristics of multicomponent flow in primary production in nanoporous reservoirs. Besides primary recovery, our long-term objectives included enhanced oil production from such reservoirs. The first step was to evaluate the phase behavior in nanopores on the basis of pore-size di

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44

Jamalbayov, M. A., Kh M. Ibrahimov, and T. M. Jamalbayli. "Determination the initial value and change behaviour of the reservoir permeability via two field measurements." SOCAR Proceedings, no. 4 (December 31, 2021): 72–79. http://dx.doi.org/10.5510/ogp20210400616.

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Abstract (sommario):

The paper proposes a technique for interpreting the results of hydrodynamic studies of volatile and non-volatile oil wells at two steady-state regimes in order to determine the initial value and coefficient of variation in effective permeability of the reservoir. It is developed based on a binary filtration model, where the hydrocarbon system is represented as consisting of two pseudocomponents and two phases, between which mass transfer of hydrocarbons takes place. The proposed methodology requires well flow rates measured at two different steady-state well conditions for two different reserv

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45

Liang, Tianbo, Rafael A. Longoria, Jun Lu, Quoc P. Nguyen, and David A. DiCarlo. "Enhancing Hydrocarbon Permeability After Hydraulic Fracturing: Laboratory Evaluations of Shut-Ins and Surfactant Additives." SPE Journal 22, no. 04 (May 17, 2017): 1011–23. http://dx.doi.org/10.2118/175101-pa.

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Abstract (sommario):

Summary Fracturing-fluid loss into the formation can potentially damage hydrocarbon production in shale or other tight reservoirs. Well shut-ins are commonly used in the field to dissipate the lost water into the matrix near fracture faces. Borrowing from ideas in chemical enhanced oil recovery (CEOR), surfactants have potential to reduce the effect of fracturing-fluid loss on hydrocarbon permeability in the matrix. Unconventional tight reservoirs can differ significantly from one another, which could make the use of these techniques effective in some cases but not in others. We present an exp

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46

Wang, Zhenliang, Shengdong Xiao, Feilong Wang, Guomin Tang, Liwen Zhu, and Zilong Zhao. "Phase Behavior Identification and Formation Mechanisms of the BZ19-6 Condensate Gas Reservoir in the Deep Bozhong Sag, Bohai Bay Basin, Eastern China." Geofluids 2021 (July 2, 2021): 1–19. http://dx.doi.org/10.1155/2021/6622795.

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Abstract (sommario):

Significant developments have been observed in recent years, in the field of deep part exploration in the Bozhong Sag, Bohai Bay Basin in eastern China. The BZ19-6 large condensate gas field, the largest gas field in the Bohai Bay Basin, was discovered for the first time in a typical oil-type basin. The proven oil and gas geological reserves in the deeply buried hills of the Archean metamorphic rocks, amount to approximately 3 × 10 8 tons of oil equivalent. However, the phase behavior and genetic mechanisms of hydrocarbon fluids are still unclear. In this study, the phase diagram identificatio

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47

Liu, Xiaoping, Zhijun Jin, Guoping Bai, Jie Liu, Ming Guan, Qinghua Pan, and Ting Li. "A comparative study of salient petroleum features of the Proterozoic–Lower Paleozoic succession in major petroliferous basins in the world." Energy Exploration & Exploitation 35, no. 1 (December 11, 2016): 54–74. http://dx.doi.org/10.1177/0144598716680308.

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Abstract (sommario):

The Proterozoic–Lower Paleozoic marine facies successions are developed in more than 20 basins with low exploration degree in the world. Some large-scale carbonate oil and gas fields have been found in the oldest succession in the Tarim Basin, Ordos Basin, Sichuan Basin, Permian Basin, Williston Basin, Michigan Basin, East Siberia Basin, and the Oman Basin. In order to reveal the hydrocarbon enrichment roles in the oldest succession, basin formation and evolution, hydrocarbon accumulation elements, and processes in the eight major basins are studied comparatively. The Williston Basin and Michi

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48

Lyu, Qixia, Weiming Wang, Qingchun Jiang, Haifeng Yang, Hai Deng, Jun Zhu, Qingguo Liu, and Tingting Li. "Basement Reservoirs in China: Distribution and Factors Controlling Hydrocarbon Accumulation." Minerals 13, no. 8 (August 9, 2023): 1052. http://dx.doi.org/10.3390/min13081052.

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Abstract (sommario):

The oil reserves of global basement reservoirs are 248 × 108 t and natural gas reserves are 2681 × 108 m3; they are crucial links in the future oil and natural gas exploration field and play an irreplaceable role in increasing oil and natural gas reserves and production. Based on research on the definition and classification of basement reservoirs, this study dissected three major basement reservoirs in China (i.e., the Dongping region located in the Qaidam Basin, the Bozhong 19-6 gas field located the Bohai Bay Basin, and the Central Uplift area of the Songliao Basin). The geological conditio

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49

Zhang, Bowei, and Guang Fu. "Prediction Method and Application of Hydrocarbon Fluid Migration through Faulted Cap Rocks." Energies 16, no. 1 (December 27, 2022): 290. http://dx.doi.org/10.3390/en16010290.

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Abstract (sommario):

Hydrocarbon fluid migration through faulted cap rocks was determined by comparing the maximum connected thickness of cap rocks required for hydrocarbon fluid migration and the actual values, since cap rocks are important in the study of hydrocarbon fluid distribution in petroliferous basins based on its migration mechanism(s). The maximum connected thickness required was identified by comparing the cap rocks, fault displacement, and oil/gas distribution. The hydrocarbon fluid at the Putaohua reservoir migrated to the overlying Saertu and Heidimiao reservoirs in the Bayan Chagan Area, northern

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He, Faqi, Ying Rao, Weihong Wang, and Yanghua Wang. "Prediction of hydrocarbon reservoirs within coal-bearing formations." Journal of Geophysics and Engineering 17, no. 3 (February 25, 2020): 484–92. http://dx.doi.org/10.1093/jge/gxaa007.

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Abstract (sommario):

Abstract This paper presents a case study on the prediction of hydrocarbon reservoirs within coal-bearing formations of the Upper Palaeozoic. The target reservoirs are low-permeability low-pressure tight-sandstone reservoirs in the Daniudi Gas Field, Ordos Basin, China. The prime difficulty in reservoir prediction is caused by the interbedding coal seams within the formations, which generate low-frequency strong-amplitude reflections in seismic profiles. To tackle this difficulty, first, we undertook a careful analysis regarding the stratigraphy and lithology of these coal-bearing formations w

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