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Artykuły w czasopismach na temat „Water coning”

Autor: Grafiati

Data publikacji: 3 czerwca 2025

Data aktualizacji: 31 lipca 2025

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1

M. Mahlil Nasution. "Metode Penanggulangan Water Coning Dari Beberapa Lapangan." JURNAL BHARA PETRO ENERGI 1, no. 3 (2022): 22–28. http://dx.doi.org/10.31599/bpe.v1i3.1740.

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The problem of vertical movement of water infiltrates the productive layer. This is often referred to as Water Coning. This water coning problem can occur because the actual production rate exceeds the critical production rate (the production rate that is allowed by a well to be produced free of coning), so that excessive suction results in a flow pressure gradient exceeding the gravitational force resulting in a breakthrough of the productive layer by water. Symptoms of water coning can be seen from surface symptoms, namely a significant increase in water content. The study wells are suspecte

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2

Wang, Rong, Kui Zhang, Yong Gang Duan, and Ting Kuan Cao. "Evaluating Water Coning Control for Horizontal Well in Bottom-Water Sandstone Reservoirs by Numerical Method." Advanced Materials Research 524-527 (May 2012): 292–96. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.292.

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Horizontal well is the main technology to develop bottom-water sandstone reservoirs. Water coning has a significant influence on development effect, and shut-in coning control is one of coning suppression methods. Based on the geological model of a given oilfield, this paper has made an evaluation of water coning control by numerical simulation. It can be concluded that the method of shut-in coning control is effective for low water cut wells. When shutting in, the lower the water cut is, the greater decline extent of water cut can be obtained and the higher cumulative oil production can be ac

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3

Adzhar, Anis Zuriati, and Sulaimon Aliyu Adebayor. "EVALUATING THE EFFECT WELL INCLINATION AND FORMATION ANISOTROPY ON CONING RATE IN DEVIATED WELLS." Platform : A Journal of Engineering 3, no. 1 (2019): 43. http://dx.doi.org/10.61762/pajevol3iss1art4985.

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In oil reservoirs with bottom water drive, coning is a fundamental problem during oil production. Horizontal and deviated wells are often used to reduce the effect of water coning on total oil production. To avoid the premature breakthrough of water, the production of oil should be maximised through effective monitoring of the critical coning rate, and many researchers have developed models to determine the critical coning rate. However, very few studies have been conducted to evaluate the effect of good inclination and formation anisotropy on the critical coning rate. Therefore, we have incor

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4

Alkhalissi, Raad Mohammed Jawad. "Single Well Coning Problem and Applicable Solutions." Iraqi Journal of Chemical and Petroleum Engineering 16, no. 2 (2015): 53–56. http://dx.doi.org/10.31699/ijcpe.2015.2.7.

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One of the most important and common problems in petroleum engineering; reservoir, and production engineering is coning; either water or gas coning. Almost 75% of the drilled wells worldwide contains this problem, and in Iraq water coning problem is much wider than the gas coning problem thus in this paper we try to clarify most of the reasons causing water coning and some of applicable solutions to avoid it using the simulation program (CMG Builder) to build a single well model considering an Iraqi well in north of Iraq black oil field with a bottom water drive, Coning was decreased by 57% by

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5

Anietie, N. Okon, Appah Dulu, and U. Akpabio Julius. "Water Coning Prediction Review and Control: Developing an Integrated Approach." Journal of Scientific Research & Reports 14, no. 4 (2017): 1–24. https://doi.org/10.9734/JSRR/2017/33291.

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In petroleum industry, oil production strategy to circumvent water coning in reservoirs with strong water drive is quit challenging. To ameliorate this oil production related problem, several water coning prediction models and control approaches have been developed by researchers. The prediction approaches include analytical, empirical and numerical approach. The analytical and empirical prediction approaches are qualitative water coning prediction approach with limited field scale application. However, these approaches model predictions can gain field application if upscale. Numerical approac

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6

Sulaimon, Aliyu Adebayo, Norlie Abdullah, and Suyash Vatsa. "ANALYSIS OF THE EFFECT OF CRITICAL PARAMETERS ON CONING IN HORIZONTAL WELLS." Platform : A Journal of Engineering 3, no. 2 (2019): 65. http://dx.doi.org/10.61762/pajevol3iss2art4988.

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Water coning is described as an upward movement of water into the perforation in oil-producing wells which lead to water production along with the crude oil. This coning may reduce oil production rate and could substantially increase water production. Hence, many correlations from previous study and available solutions were investigated to estimate the actual critical oil rate to control water-coning in horizontal wells. Specifically, the effects of fluid and rock properties such as viscosity, formation thickness, horizontal permeability, length of horizontal wells and density difference betwe

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7

Ali, Frzan F., Maha R. Hamoudi, and Akram H. Abdul Wahab. "Comparison Between Homogenous and Heterogeneous Reservoirs: A Parametric Study of Water Coning Phenomena." UKH Journal of Science and Engineering 5, no. 1 (2021): 119–31. http://dx.doi.org/10.25079/ukhjse.v5n1y2021.pp119-131.

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Water coning is the biggest production problem mechanism in Middle East oil fields, especially in the Kurdistan Region of Iraq. When water production starts to increase, the costs of operations increase. Water production from the coning phenomena results in a reduction in recovery factor from the reservoir. Understanding the key factors impacting this problem can lead to the implementation of efficient methods to prevent and mitigate water coning. The rate of success of any method relies mainly on the ability to identify the mechanism causing the water coning. This is because several reservoir

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8

Farmen, Jonn-Erik, Geri Wagner, Unni Oxaal, Paul Meakin, Jens Feder, and Torstein Jøssang. "Dynamics of water coning." Physical Review E 60, no. 4 (1999): 4244–51. http://dx.doi.org/10.1103/physreve.60.4244.

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9

Li, Yahui, Haitao Li, and Ying Li. "Prediction Method of Bottom Water Coning Profile and Water Breakthrough Time in Bottom Water Reservoir without Barrier." Mathematical Problems in Engineering 2015 (2015): 1–6. http://dx.doi.org/10.1155/2015/149490.

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During the exploitation of bottom water oil reservoir, bottom water coning influences the breakthrough of bottom water significantly. Because water cut rises quickly after the breakthrough of bottom water, measures should be taken before the breakthrough to postpone production period without water, thus improving oil recovery. So accurate prediction of water coning profile and breakthrough time is very essential. Through mathematical derivation, this paper proposed a prediction method of bottom water coning profile and bottom water breakthrough time in bottom water reservoir without barrier. B

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10

Shan, Wu Yi, and Xue Zhang. "The Research for Delaying the Bottom Water Coning in Horizontal Wells Application Balance Screen Pipe." Advanced Materials Research 734-737 (August 2013): 1480–83. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1480.

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When horizontal wells are used to exploit reservoir with bottom water, oil wells water breakthrough prematurely due to water coning, water-free oil recovery is reduced. The reason of the formation of horizontal well water cone is analyzed. Then analysis of the mechanism using balanced screen pipe to inhibit bottom water coning in horizontal well is completed. According to the existing screen pipe size, screen configuration is optimized. Horizontal section pressure distribution is controlled by the balanced screen pipe, and then flow of horizontal well sections is adjusted. Bottom water coning

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11

Baderestani, Hossein, Heshmat Amirzadeh, and Javad Banavi. "The Field Scale Investigation of Water Coning Phenomenon." Applied Mechanics and Materials 157-158 (February 2012): 319–22. http://dx.doi.org/10.4028/www.scientific.net/amm.157-158.319.

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The study of water coning phenomenon has gained wide interest in petroleum industry during the last few decades and poses a challenge for hydrocarbon production. The simultaneous production of water and oil causes lots of negative effects on the reservoir performance such as significant reduction in oil recovery, corrosion, the cost of oil and water separation, environmental pollutions, and etc. Hence investigation of water coning and finding some solutions seems highly noticeable. For that, we model one of the Norwegian reservoirs which encounters water coning problem by using a black oil sim

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12

Emara, Ramadan. "WATER CONING CORRELATIONS IN VERTICAL WELLS." Journal of Al-Azhar University Engineering Sector 12, no. 42 (2017): 213–22. http://dx.doi.org/10.21608/auej.2017.19301.

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13

Tang, Jian-Gang, Zharasbek D. Baishemirov, and Bakhbergen E. Bekbauov. "Preventing water coning by polymer flooding." International Journal of Academic Research 4, no. 6 (2012): 292–301. http://dx.doi.org/10.7813/2075-4124.2012/4-6/a.42.

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14

Saleh, Talib A., and Shaker M. Khalaf. "WATER CONING IN ASMARY RESERVOIR-FAUQI FIELD." Journal of Engineering 15, no. 04 (2009): 4339–46. http://dx.doi.org/10.31026/j.eng.2009.04.15.

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Water coning in oil wells is one of the most serious problem because when the water reach to perforated zone, it will be produced with oil. Water with oil will form other problems in refinery, such as corrosion, and it will affect the purity of different petroleum products.The present work deals with fauqi field Asmari reservoir which is an active water drive reservoir.An empirical equation has been proposed to calculate the critical production rate. This equation is obtained by regression of the data which are collected from Missan oil field. The proposed equation gives better results than Sc

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15

Qu, Jie, Pan Wang, Qing You, Guang Zhao, Yongpeng Sun, and Yifei Liu. "Soft Movable Polymer Gel for Controlling Water Coning of Horizontal Well in Offshore Heavy Oil Cold Production." Gels 8, no. 6 (2022): 352. http://dx.doi.org/10.3390/gels8060352.

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Horizontal well water coning in offshore fields is one of the most common causes of rapid declines in crude oil production and, even more critical, can lead to oil well shut down. The offshore Y oil field with a water cut of 94.7% urgently needs horizontal well water control. However, it is a challenge for polymer gels to meet the requirements of low-temperature (55 °C) gelation and mobility to control water in a wider range. This paper introduced a novel polymer gel cross-linked by hydrolyzed polyacrylamide and chromium acetate and phenolic resin for water coning control of a horizontal well.

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16

Гончаров, И. И. "OIL RECOVERY USING THE REVERSE CONE METHOD TO IMPROVE THE EFFICIENCY OF DEVELOPING OIL-WATER ZONES." Бурение и нефть, no. 6 (May 16, 2024): 3–5. http://dx.doi.org/10.62994/2072-4799.2024.57.83.003.

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Статья посвящена проблематике разработки месторождений или их частей, подстилаемых подошвенной пластовой водой. Описаны основные принципы образования конусов подошвенных вод. Для борьбы с активным конусообразованием, в том числе на действующем фонде, автором предлагается адаптированная технология отбора нефти методом обратного конуса. The article is devoted to the problems of developing fields or their parts underlain by bottom formation water. The basic principles of the formation of bottom water cones are described. To combat active coning, including in existing reservoirs, the author propos

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17

UEDA, Yoshiaki, Kazuya KOYAMA, and Kazuo FUJITA. "The study of water coning for bottom water drive reservoir." Journal of the Japanese Association for Petroleum Technology 53, no. 6 (1988): 517–24. http://dx.doi.org/10.3720/japt.53.517.

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18

Tang, Xiujun, Xiao Li, Chen Yang, and Ling Li. "Study on the Adaptability of Jurassic Nitrogen Foam Cone Pressing." E3S Web of Conferences 406 (2023): 02005. http://dx.doi.org/10.1051/e3sconf/202340602005.

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Aiming at the problems of bottom water coning and oil well flooding caused by the large impact of the early production strength of the Jurassic bottom water direct contact well in the Seventh Oil Production Plant. Carry out research on nitrogen foam control bottom water coning technology, mainly including: ①laboratory test to optimize foam system suitable for Jurassic system of No. 7 Oil Production Plant, determine injection concentration and optimal gas-liquid ratio; ②The nitrogen foam injection timing and shut in time were optimized by numerical simulation method; ③Summarize the field tests

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19

Safari, Mehdi, and Mohammad Javad Ameri. "Reservoir Control and Identification: Motivated by Water Coning." IOP Conference Series: Materials Science and Engineering 495 (June 7, 2019): 012079. http://dx.doi.org/10.1088/1757-899x/495/1/012079.

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20

Ould-amer, Y., S. Chikh, and H. Naji. "Attenuation of water coning using dual completion technology." Journal of Petroleum Science and Engineering 45, no. 1-2 (2004): 109–22. http://dx.doi.org/10.1016/j.petrol.2004.04.004.

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21

Bruining, J., C. J. Van Duijn, and R. J. Schotting. "Simulation of coning in bottom water-driven reservoirs." Transport in Porous Media 6, no. 1 (1991): 35–69. http://dx.doi.org/10.1007/bf00136821.

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22

Veliyev, E. F. "Prediction methods for coning process." Azerbaijan Oil Industry, no. 3 (March 15, 2021): 18–25. http://dx.doi.org/10.37474/0365-8554/2021-3-18-25.

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Currently, the percentage of the mature fields steadily rise and the process of formation of water and gas cones becomes unavoidable. The prediction of this process is essential for successful field development. Correlation dependencies developed for this purpose can be divided into three main groups. The models in the first group are based on the analytical approach of definition of balance conditions for viscous and gravitational powers in the reservoir. The methods in the second group are based on empiric approach, i.e. on the data obtained as a result of laboratory experiments or computer

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23

Fattahanisa, Aqlyna, Rini Setiati, Arinda Ristawati, and Puri Wijayanti. "QUALITATIVE AND QUANTITATIVE ANALYSIS OF WATER CONING AND BREAKTHROUGH TIME PREDICTION ON ZNC FIELD." Journal of Petroleum and Geothermal Technology 4, no. 2 (2023): 24. http://dx.doi.org/10.31315/jpgt.v4i2.10108.

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Given the current public need for oil and gas as a primary energy, all oil and gas companies need to increase production to meet this demand. One of the things companies usually do to achieve this is to evaluate and analyze the productivity of each well. Of course, production decreases from time to time, so the company must try to increase its production. One of the reasons for the decline in oil production from the ZNC-1 well in the ZNC Field is the production of excessive water content. There are several factors that cause excessive water content in oil wells, and this is called water coning

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24

Huang, Xiao He, Wei Yao Zhu, and Yu Lou. "Water Coning Simulation Mode in Fractured Gas Reservoir with Bottom Water." Applied Mechanics and Materials 423-426 (September 2013): 1716–21. http://dx.doi.org/10.4028/www.scientific.net/amm.423-426.1716.

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There are two percolation models, horizontal radial flow above perforation interval, and semispherical centripetal flow below perforation interval. Based on this models and the theory of percolation flow through porous media, a study on prediction of water breakthrough time in fractured gas reservoir with bottom water is presented. Through mathematical calculations, a formula to determine the time of water breakthrough in fractured gas reservoir with bottom water wells is derived. Case study indicates that water breakthrough time decreases with the fracture development index. With increase of

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25

Altaher, Al-Hussein, Maha Hamoudi, and Akram Humoodi. "Delaying Water Breakthrough Using Horizontal Wells in Khurmala Oilfield." Iraqi Geological Journal 56, no. 2E (2023): 208–21. http://dx.doi.org/10.46717/igj.56.2e.15ms-2023-11-20.

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Water coning presents a serious problem in many oil fields, in terms of reducing oil production rate and increasing production costs. As breakthrough time represents the time until coning occurs, it should be increased by studying the significant affecting parameters and proposing a method to control them. Since horizontal wells are known to have higher potentials than vertical wells, they are used worldwide to delay water coning among other purposes. In this study, four designed horizontal wells are proposed to replace a drilled vertical well in Khurmala oilfield in northern Iraq, and the eff

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26

Al-Attar, Mazin H., and Dr Mohammed S. Al-Jawad. "Single-Well Modeling Study In Buzurkan Oil Field." Journal of Petroleum Research and Studies 2, no. 3 (2021): 132–41. http://dx.doi.org/10.52716/jprs.v2i3.51.

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Single well modeling technique is considered as an important tool in simulation studies that deal with the near well issues (i.e. water coning, optimum perforation intervals, etc.); or it may be used in the determination of the final acceptability of the entire field model (1). In this study, this technique is adopted to study and characterize one of the producing wells in Buzurkan oil field which is BU-3. The probability of the increase of water production will be tested with different production schemes, because if the well has to produce with certain water rate, the surface facilities have

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27

Wojtanowicz, Andrew K., and Miguel Armenta. "Assessment of Down-Hole Water Sink Technology for Controlling Water Inflow at Petroleum Wells." Journal of Energy Resources Technology 126, no. 4 (2004): 334–41. http://dx.doi.org/10.1115/1.1831282.

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Water inflow to petroleum wells hampers production of oil or gas leading to early shut downs of the wells without sufficient recovery of hydrocarbons in place. Downhole water sink (DWS) is a completion/production technique for producing water-free hydrocarbons with minimum amount of water from reservoirs with bottom water drive and strong tendency to water coning. DWS eliminates water invasion to hydrocarbon production by employing hydrodynamic mechanism of coning control in situ at the oil-water or gas-water contact. The mechanism is based upon a localized water drainage generated by another

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28

Tabatabaei, Mohammad, Ali Ghalambor, and Boyun Guo. "An Analytical Solution for Water Coning in Vertical Wells." SPE Production & Operations 27, no. 02 (2012): 195–204. http://dx.doi.org/10.2118/113106-pa.

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Ndarake Okon, Anietie. "Water Coning Prediction: An Evaluation of Horizontal Well Correlations." Engineering and Applied Sciences 3, no. 1 (2018): 21. http://dx.doi.org/10.11648/j.eas.20180301.14.

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Høyland, Leif A., Paul Papatzacos, and Svein M. Skjaeveland. "Critical Rate for Water Coning: Correlation and Analytical Solution." SPE Reservoir Engineering 4, no. 04 (1989): 495–502. http://dx.doi.org/10.2118/15855-pa.

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Shen, Wei-jun, Xiao-hua Liu, Xi-zhe Li, and Jia-liang Lu. "Water coning mechanism in Tarim fractured sandstone gas reservoirs." Journal of Central South University 22, no. 1 (2015): 344–49. http://dx.doi.org/10.1007/s11771-015-2528-4.

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YAKUPOV, R. F., V. S. MUKHAMETSHIN, and K. T. TYNCHEROV. "FILTRATION MODEL OF OIL CONING IN A BOTTOM WATER-DRIVE RESERVOIR." Periódico Tchê Química 15, no. 30 (2018): 725–33. http://dx.doi.org/10.52571/ptq.v15.n30.2018.725_periodico30_pgs_725_733.pdf.

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The purpose of the paper is the substantiation of the application of the oil coning technology in the process of the hydrodynamic simulation of the successive method, which includes the perforation of the casing below the level of oil-water contact; the drawing of water from the lower water-saturated part of the reservoir; the isolation of this perforation interval; the drilling-in of the near-caprock oil-saturated part of the reservoir and the production of near-caprock oil. The leading approach to the research of this problem is the method of filtration modeling of the oil and water coning p

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Rajagopalan, S. P., and U. V. Jose. "Digital Simulation Model for Brine Coning in Unconfined Anisotropic Aquifers." Hydrology Research 18, no. 1 (1987): 43–58. http://dx.doi.org/10.2166/nh.1987.0004.

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A digital simulation model has been presented for locating the steady state stable brine cone position beneath partially penetrating wells tapping from the fresh water zone overlying a saline zone in an unconfined anisotropic aquifer. A graphical procedure developed by Morris Muskat has been converted into a numerical one and is used to successively approximate the brine cone position. The truncation in the fresh water zone both due to the brine cone and the depression in the water table are taken care of by repeated adjustment of the hydraulic conductances of the affected branches in the nume

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34

Okon, Anietie, Dulu Appah, and Julius Akpabio. "Water Coning Prediction Review and Control: Developing an Integrated Approach." Journal of Scientific Research and Reports 14, no. 4 (2017): 1–24. http://dx.doi.org/10.9734/jsrr/2017/33291.

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Ndarake Okon, Anietie. "A Critical Evaluation of Water Coning Correlations in Vertical Wells." American Journal of Science, Engineering and Technology 3, no. 1 (2018): 1. http://dx.doi.org/10.11648/j.ajset.20180301.11.

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Abdel Azim, Reda. "Evaluation of water coning phenomenon in naturally fractured oil reservoirs." Journal of Petroleum Exploration and Production Technology 6, no. 2 (2015): 279–91. http://dx.doi.org/10.1007/s13202-015-0185-7.

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Wojtanowicz, Andrew K., Hui Xu, and Zaki Bassiouni. "Segregated production method for oil wells with active water coning." Journal of Petroleum Science and Engineering 11, no. 1 (1994): 21–35. http://dx.doi.org/10.1016/0920-4105(94)90060-4.

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Baishemirov, Zharasbek D., Bakhbergen E. Bekbauov, and Aidarkhan Kaltayev. "A numerical study of methods to preventbottom water from coning." International Journal of Academic Research 4, no. 4 (2012): 158–71. http://dx.doi.org/10.7813/2075-4124.2012/4-4/a.23.

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Forbes, Lawrence K., Graeme C. Hocking, and Simon Wotherspoon. "Salt-water up-coning during extraction of fresh water from a tropical island." Journal of Engineering Mathematics 48, no. 1 (2004): 69–91. http://dx.doi.org/10.1023/b:engi.0000009517.28682.6f.

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Jin, Lu, and Andrew K. Wojtanowicz. "Performance Analysis of Wells With Downhole Water Loop Installation for Water Coning Control." Journal of Canadian Petroleum Technology 49, no. 06 (2010): 38–45. http://dx.doi.org/10.2118/138402-pa.

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Irrgang, H. R. "EVALUATION AND MANAGEMENT OF THIN OIL COLUMN RESERVOIRS IN AUSTRALIA." APPEA Journal 34, no. 1 (1994): 64. http://dx.doi.org/10.1071/aj93005.

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Thin oil columns represent a common and important class of hydrocarbon reserve which are notoriously difficult to evaluate and produce. This paper provides case studies of examples of these reservoirs in Australia and summarises the production methods, well performance and recovery efficiencies.Thin oil column reservoirs are defined here as reservoirs which will cone both water and gas when produced at commercial rates. The oil zone can have a pancake or rim geometry. Examples within Australia include Bream and Snapper (Gippsland Basin), South Pepper and Chervil (Carnarvon Basin), Chookoo (Ero

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42

Faleh, Almanar, and Jalal A. Al-Sudani. "Estimation of Water Breakthrough Using Numerical Simulation." Association of Arab Universities Journal of Engineering Sciences 26, no. 3 (2019): 73–81. http://dx.doi.org/10.33261/jaaru.2019.26.3.009.

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Water coning is one of the most important phenomena that affect the oil production from oil reservoirs having bottom water aquifers. Empirical model has been developed based on numerical simulator results verified for wide range variation of density difference, viscosity ratio, perforated well interval, vertical to horizontal permeability ratio and well to reservoir radius ratio; the effect of all these parameters on breakthrough time of raising water have been recorded for five different oil flow rate. Since, the model reflects the real situations of reservoir-aquifer zone systems; in which t

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43

Veliyev, E. F., A. A. Aliyev, and T. E. Mammadbayli. "Machine learning application to predict the efficiency of water coning prevention." SOCAR Proceedings, no. 1 (March 30, 2021): 104–13. http://dx.doi.org/10.5510/ogp20210100487.

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The increase in number of the mature fields is accompanied by an increase in the water cut of the produced fluids. One of the most common causes of this phenomenon is the process of water coning, that is, the breakthrough of the bottom water to the wellbore, in which water flows form a figure similar to a cone. The paper proposes a ranking mechanism based on machine learning methods that allow to significantly reduce the resource intensity of existing prediction models. In order to preserve the simplicity of presentation, the proposed mechanism is considered on the example of one technology -

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Lucas, S. K., J. R. Blake, and A. Kucera. "A boundary-integral method applied to water coning in oil reservoirs." Journal of the Australian Mathematical Society. Series B. Applied Mathematics 32, no. 3 (1991): 261–83. http://dx.doi.org/10.1017/s0334270000006858.

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AbstractIn oil reservoirs, the less-dense oil often lies over a layer of water. When pumping begins, the oil-water interface rises near the well, due to the suction pressures associated with the well. A boundary-integral formulation is used to predict the steady interface shape, when the oil well is approximated by a series of sources and sinks or a line sink, to simulate the actual geometry of the oil well. It is found that there is a critical pumping rate, above which the water enters the oil well. The critical interface shape is a cusp. Efforts to suppress the cone by using source/sink comb

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Ndarake Okon, Anietie, and Dulu Appah. "Integrated-reservoir-model-based critical oil rate correlation for vertical wells in thin oil rim reservoirs in the Niger Delta." International Journal of Engineering & Technology 7, no. 3 (2018): 1757. http://dx.doi.org/10.14419/ijet.v7i3.15426.

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Thin oil rim reservoirs are mostly characterized by development and production challenges; one of which is early water coning tendency. In the Niger Delta, most developed critical oil rate correlations to avert coning focused on conventional bottom-water drive reservoirs, while thin oil rim reservoirs received limited attention. Available correlations to estimate critical oil rate of thin oil rim reservoirs in Niger Delta are based on generic reservoir models, which does not consider the reservoir heterogeneity. Hence, it leaves these available correlations’ predictions in doubt, considering t

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Moortgat, Joachim, and Abbas Firoozabadi. "Water Coning, Water, and CO₂ Injection in Heavy-Oil Fractured Reservoirs." SPE Reservoir Evaluation & Engineering 20, no. 01 (2017): 168–83. http://dx.doi.org/10.2118/183648-pa.

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Duan, Shengkai, Xin Li, and Andrew K. Wojtanowicz. "Dynamic growth of water saturation around oil wells by water coning and transverse dispersion." Journal of Petroleum Science and Engineering 78, no. 2 (2011): 447–53. http://dx.doi.org/10.1016/j.petrol.2011.06.015.

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Al-Mudhafar, Watheq J., Dandina N. Rao, and Andrew K. Wojtanowicz. "Leveraging Designed Simulations and Machine Learning to Develop a Surrogate Model for Optimizing the Gas–Downhole Water Sink–Assisted Gravity Drainage (GDWS-AGD) Process to Improve Clean Oil Production." Processes 12, no. 6 (2024): 1174. http://dx.doi.org/10.3390/pr12061174.

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The Gas and Downhole Water Sink–Assisted Gravity Drainage (GDWS-AGD) process addresses gas flooding limitations in reservoirs surrounded by infinite-acting aquifers, particularly water coning. The GDWS-AGD technique reduces water cut in oil production wells, improves gas injectivity, and optimizes oil recovery, especially in reservoirs with high water coning. The GDWS-AGD process installs two 7-inch production casings bilaterally. Then, two 2-3/8-inch horizontal tubings are completed. One tubing produces oil above the oil–water contact (OWC) area, while the other drains water below it. A hydra

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Mantilla, Cesar A., Sanjay Srinivasan, and Quoc P. Nguyen. "Updating Geologic Models using Ensemble Kalman Filter for Water Coning Control." Engineering 03, no. 05 (2011): 538–48. http://dx.doi.org/10.4236/eng.2011.35063.

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Salavatov, T. Sh, and Al Sayed Ghareeb. "Predicting the behavior of water and gas coning in horizotal wells." "Proceedings" of "OilGasScientificResearchProjects" Institute, SOCAR, no. 2 (June 30, 2010): 31–41. http://dx.doi.org/10.5510/ogp20100200019.

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