Bibliografie tematiche / Critical coning rate

Letteratura scientifica selezionata sul tema "Critical coning rate"

Autore: Grafiati
Pubblicato: 4 giugno 2021
Ultima modifica: 19 febbraio 2022

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Articoli di riviste sul tema "Critical coning rate"

1

Høyland, Leif A., Paul Papatzacos e Svein M. Skjaeveland. "Critical Rate for Water Coning: Correlation and Analytical Solution". SPE Reservoir Engineering 4, n. 04 (1 novembre 1989): 495–502. http://dx.doi.org/10.2118/15855-pa.

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2

Ndarake Okon, Anietie, e 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, n. 3 (21 agosto 2018): 1757. http://dx.doi.org/10.14419/ijet.v7i3.15426.

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Abstract (sommario):
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 the sensitive nature of developing thin oil rim reservoirs. Thus, a correlation for critical oil rate (qc) based on integrated reservoir model in the Niger Delta was develop for thin oil rim reservoirs using multivariable numerical optimization approach. The obtained result indicated that the developed correlation predicted 226.05 bbl/day compared to the actual Oilfield critical oil rate of 226.11 bbl/day. Furthermore, sensitivity study indicated that the developed correlation and the integrated reservoir model predictions of fractional well penetration (hp/h) and height below perforation - oil column (hbp/h) on critical oil rate (qc) were close and resulted in coefficient of determination (R2) of 0.9266 and 0.9525, Chi square (X2) of 0.539 and 0.655, and RMSE of 4.336 and 4.357. Additionally, the results depict that critical oil rate depends indirectly on fractional well penetration and directly on height above perforation for vertical wells. Therefore, to delay water-coning tendency in thin oil rim reservoirs these completion parameters are consideration in vertical wells to establish optimum critical oil rate during hydrocarbons production. Also, the developed correlation can be used as a quick tool to estimate critical oil rate of thin oil rim reservoirs in the Niger Delta.
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3

Bahadori, Alireza, e Alireza Nouri. "Prediction of critical oil rate for bottom water coning in anisotropic and homogeneous formations". Journal of Petroleum Science and Engineering 82-83 (febbraio 2012): 125–29. http://dx.doi.org/10.1016/j.petrol.2012.01.016.

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4

Prasun, Samir, e Andrew K. Wojtanowicz. "Semi-analytical prediction of critical oil rate in naturally fractured reservoirs with water coning". Journal of Petroleum Science and Engineering 180 (settembre 2019): 779–92. http://dx.doi.org/10.1016/j.petrol.2019.05.082.

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5

HOCKING, G. C., e H. ZHANG. "A NOTE ON AXISYMMETRIC SUPERCRITICAL CONING IN A POROUS MEDIUM". ANZIAM Journal 55, n. 4 (aprile 2014): 327–35. http://dx.doi.org/10.1017/s1446181114000170.

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Abstract (sommario):
AbstractThe steady response of a fluid with two layers of different density in a porous medium is considered during extraction through a point sink. Supercritical withdrawal in which both layers are being withdrawn is investigated using a spectral method. We show that for each withdrawal rate, there is a single entry angle of the interface into the point sink. As the flow rate decreases the angle of entry steepens until it becomes almost vertical, at which point the method fails. This limit is shown to correspond to the upper bound on sub-critical (single-layer) flow.
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6

Lucas, S. K., J. R. Blake e A. Kucera. "A boundary-integral method applied to water coning in oil reservoirs". Journal of the Australian Mathematical Society. Series B. Applied Mathematics 32, n. 3 (gennaio 1991): 261–83. http://dx.doi.org/10.1017/s0334270000006858.

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Abstract (sommario):
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 combinations are presented.
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7

Balhasan, Saad A., e Daniel A. Michael. "Case Study on Determining the Critical Production Rate for Bottom Water Coning in the Majed (EE-Pool) Reservoir". Journal of Engineering and Applied Sciences 15, n. 4 (20 novembre 2019): 925–31. http://dx.doi.org/10.36478/jeasci.2020.925.931.

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8

Smulski, Rafał. "Comparative Analysis of Selected Models of Water Coning in Gas Reservoirs / Analiza Porównawcza Wybranych Modeli Powstawania Stożków Wodnych w Złożach Gazowych". Archives of Mining Sciences 57, n. 2 (12 novembre 2012): 451–70. http://dx.doi.org/10.2478/v10267-012-0030-5.

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Abstract (sommario):
Abstract Exploitation of natural gas fields with edge or underlying water is usually defined per analogy to the oil fields. The existing models do not correspond to reality as they do not describe relevant processes related with a turbulent gas flow near the well. The natural gas exploitation with productivity greater than critical may be advantageous in view of summaric depletion and rate of depletion. Article presents: the analysis of the selected critical rates models, determining the influence of specific parameters on the critical rate values, introducing new modified formula for critical rates, and comparative calculations for various configurations with the numerical model.
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9

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

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Abstract (sommario):
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 perforated degree, water breakthrough time increase first and then decreased after a critical value, which could be considered as optimum perforation degree. If the perforated degree is fixed, the water breakthrough time is directly proportional to the thickness of the gas reservoir and inversely proportional to the gas production rate.
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10

AL-ALI, S., G. C. HOCKING e D. E. FARROW. "CRITICAL SURFACE CONING DUE TO A LINE SINK IN A VERTICAL DRAIN CONTAINING A POROUS MEDIUM". ANZIAM Journal 61, n. 3 (luglio 2019): 249–69. http://dx.doi.org/10.1017/s1446181119000099.

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Abstract (sommario):
The withdrawal of water with a free surface through a line sink from a two-dimensional, vertical sand column is considered using the hodograph method and a novel spectral method. Hodograph solutions are presented for slow flow and for critical, limiting steady flows, and these are compared with spectral solutions to the steady problem. The spectral method is then extended to obtain unsteady solutions and hence the evolution of the phreatic surface to the steady solutions when they exist. It is found that for each height of the interface there is a unique critical coning value of flow rate, but also that the value obtained is dependent on the flow history.
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Più fonti

Tesi sul tema "Critical coning rate"

1

Khalili, Ali Petroleum engineering UNSW. "A review of critical coning rate correlations and identifying the most reliable equation". Awarded by:University of New South Wales. Petroleum engineering, 2005. http://handle.unsw.edu.au/1959.4/22388.

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Abstract (sommario):
The study of coning in oil production is important because of huge water production associated with oil production around the world each year. Estimation of critical coning rate has been the subject of numerous studies and a number of correlations have been reported. This study presents a review of the current available methods for estimating critical coning rate for both vertical and horizontal wells. The various methods and correlations are compared and the assumptions on which they are based evaluated. Following comparison made between the correlations, the most reliable theories are identified for both vertical and horizontal wells separately. Among the correlations for vertical wells, this study recommends two implicit methods presented by Wheatley and Azar Nejad et al. They determined the oil potential distribution influenced by water cone with a remarkable accuracy. For horizontal wells, two methods, Joshi???s equation and Rechem et al formula, are considered to be the most reliable. Joshi???s equation provides lower estimates than Chaperon???s correlation in which the water cone effect on oil potential was neglected. The Recham et al formula also gives a similar result. On the whole, the Rechem et al method is preferred.
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2

Huang, Shiang-Yun, e 黃湘芸. "Study of Breakthrough Time and Critical Oil Production Rate for a Water Coning Reservoir". Thesis, 2006. http://ndltd.ncl.edu.tw/handle/63005322768498040197.

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Abstract (sommario):
碩士
國立成功大學
資源工程學系碩博士班
94
The purposes of this study are to develop a numerical model to study water coning in an oil-water reservoir, to predict the water coning breakthrough from oil-water contact (OWC) in a production well and to estimate the critical oil production rate. The critical oil production rate is the maximum oil production rate with no water produced. This study is also to investigate the phenomena of water coning decline after producing well is shutting in. A numerical model with a partial-penetration-oil-producing well in an oil-water reservoir is developed for studying the water coning breakthrough, water coning decline and critical production rate. Based on the results of numerical study, the relationship between the dimensionless water coning breakthrough time (tBT)D and the dimensionless production rate (qD) can be expressed as (tBT)D=9.34*10^-8*qD^-12.36 . By using this equation, the dimensionless critical rate is 0.13 for the being approached to infinite. For the production well is shutting-in when the water coning approaches to the bottom of the perforation internal, the results show that the dimensionless water coning decline time is increasing as the dimensionless production rate decreasing. In comparing the critical rates, the results from simulation are slightly higher then these from analytical solutions existed in literature. The water coning breakthrough time from simulation is close to Hagoort’s model; and the result from numerical model is lower than it from Sobocinski and Cornelius’ model, but higher than it from Bournzal and Jeanson’s model .
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3

Chou, Kuei-Tzu, e 鄒貴慈. "Analysis of Water Coning Behavior with Critical Rate and Breakthrough Time via Numerical Simulation Method". Thesis, 2005. http://ndltd.ncl.edu.tw/handle/25123311510624151335.

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Abstract (sommario):
碩士
國立成功大學
資源工程學系碩博士班
93
Water coning or water cut sometimes appears and shorts the production rate of the well in the oil field when the withdrawal rate exceeds the critical production rate. In literature, the analytical solution of critical rate assumed that the coning effective radius (r1) is given and directly used the reservoir boundary (re). However, the coning effective radius is unknown. 　The purpose of this study is using numerical simulation to build up water coning simulation model, to study the influences of critical rate and breakthrough time by water coning, and to establish the relationship between the coning effective radius and the critical rate according the result. 　First, we simulate the change of water coning on different critical rates and permeabilities to plot the coning height (h) versus time (t). Then we use the critical rate analytical model, including Meyer and Garder (1954), and Schols (1972). The coning effective radius is assumed, and the reservoir boundary is directly used. After calculating the critical values respectively, we compare these critical values with the simulation values. From the results, the calculation of Meyer and Garder (Meyer and Garder, 1954) is relatively conservative, that is, is lower than the simulation and the water breakthrough of the well will not appear. The calculation of Schols (Schols, 1972) under various permeabilities outstrips the simulation result. 　In study of breakthrough time, the time of water coning rising to the bottom of well is compared with the Hagoort’s analytical solution. The results of two calculations are very close. 　About the critical rate and breakthrough time models, we simulate the coning effective radius (rc) and calculate the dimensionless coning effective radius (rcD) versus dimensionless time (tD). Also, we study the relationship between pressure effective radius (ri) and coning effective radius, and obtain the relationship equation of . This equation can be used correctly in calculating the coning critical rate.
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4

Peng, Yu-Fong, e 彭于峰. "Numerical Simulation Study of Breakthrough of Water Conning and Critical Rate for Horizontal Oil Well". Thesis, 2007. http://ndltd.ncl.edu.tw/handle/79006432688523880141.

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Abstract (sommario):
碩士
國立成功大學
資源工程學系碩博士班
95
The purpose of this study is to develop a water conning numerical model of a horizontal well for studying the relationship between the conning breakthrough time and the production rate, and for estimating the critical production rate. The effects of well location, length of the horizontal section, capillary pressure, and formation anisotropy on the critical production rate are considered in the model. A black-oil model simulator, IMEX from CMG, is used in this study to simulate the behavior of water conning of horizontal well. The results of the relationship of the coning breakthrough time and the production rate from simulation study are used to establish the coning breakthrough time type curves. These type curves can be used to estimate the critical production rate of horizontal well. The results of this study show that: (1) The critical production rate for a formation with capillary pressure is smaller than that without capillary pressure; (2) The higher critical production rate will be obtained the higher well location; (3) The higher critical production rate will be higher for the longer horizontal section; (4) In the case of anisotropic formation, critical production rate will be higher for the smaller ratio of vertical/horizontal permeability; (5) The critical production rate for a horizontal well is higher than that of a vertical well; thus, the producitivity of a horizontal well is better than that of a vertical well.
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Atti di convegni sul tema "Critical coning rate"

1

Abass, H. H., e D. M. Bass. "The Critical Production Rate in Water-Coning System". In Permian Basin Oil and Gas Recovery Conference. Society of Petroleum Engineers, 1988. http://dx.doi.org/10.2118/17311-ms.

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2

Ling, Kegang, e Zheng Shen. "Including the Effect of Capillary Pressure to Estimate Critical Rate in Water Coning Well". In North Africa Technical Conference and Exhibition. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/152131-ms.

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3

Konieczek, J. "The Concept of Critical Rate in Gas Coning and Its Use in Production Forecasting". In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1990. http://dx.doi.org/10.2118/20722-ms.

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4

Ekeregbe, Merit P. "Determination of Optimum Rate in a Condensate Well with a Case of a Wellbore Liquid Loading". In SPE Nigeria Annual International Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/207119-ms.

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Abstract (sommario):
Abstract Condensate reservoirs are mostly pressure sensitive and keeping the pressure above the dew point pressure in the reservoir is critical to avoid condensate banking in the reservoir. If it occurs, production is highly inhibited and the well may ultimately quit on production under liquid loading. Fluid ratios are important in the management of condensate wells and most critical is the Gas Liquid Ratio (GLR). There is a certain GLR that below it, there will be a liquid loading in the wellbore that could quit the well. Each fluid rate goes with a GLR and the point where there is a reversal of the GLR or CGR trends may present a case of loading scenario and that is taken as the determination reference point. When a condensate well shows an improvement of water cut as the choke bean size is reduced does not necessarily signify a healthy situation and neither a one-point higher water cut with increase in choke bean size mean a water coning situation. When a liquid loading well is beaned up, there is early signs of water coning in the production data but this is just a wellbore production and the BS&W improves as the production rate is further increased. Further investigation is necessary to separate the challenge of water conning from the challenge of too low Gas rate which causes the loading of the liquids in the wellbore. That is the operating envelop to manage condensate well rates: rates too low with a possibility of a liquid loading and rates too high that depicts a case of water conning when water is close to the perforation. This band must be completely exploited to turn the production curve in the positive. This paper provides a strategy to recover a condensate well production with a challenge of liquid loading using a case study. The degree of the severity of the liquid loading can be represented using a power law model with the gradient being the level of severity of the loading. The production improvement is greater than nβ percent where n is the quadratic model number 2 and β is the product of the graphical and Lagrangian-Quadratic alpha parameters. The optimum rate can be determined using the Lagrange Multiplier optimization method to effectively extend the production life of the well.
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5

Recham, R. "Super-Critical Rate Based on Economic Recovery in Water and Gas Coning by Using Vertical and Horizontal Well Performance". In Canadian International Petroleum Conference. Petroleum Society of Canada, 2001. http://dx.doi.org/10.2118/2001-024.

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Recham, R. "Super-Critical Rate Based on Economic Recovery in Water and Gas Coning by Using Vertical and Horizontal Well Performance". In SPE Offshore Europe Oil and Gas Exhibition and Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/71820-ms.

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7

Menouar, H. K., e A. A. Hakim. "Water Coning And Critical Rates In Vertical And Horizontal Wells". In Middle East Oil Show. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/29877-ms.

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8

Chaperon, I. "Theoretical Study of Coning Toward Horizontal and Vertical Wells in Anisotropic Formations: Subcritical and Critical Rates". In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1986. http://dx.doi.org/10.2118/15377-ms.

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9

Hidalgo, Oswaldo Jose, Luis Brito, Ramon Garrido, Julio Munoz, Freddy Paz, Francisco Flamenco-Lopez e Roberto Aguilera. "Critical Oil Rates in Naturally Fractured Reservoirs to Minimize Gas and Water Coning: Case History of a Mexican Carbonate Reservoir". In Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/121743-ms.

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10

Espinola, O., J. D. Guzman, Reza Mehranfar e H. Pineda. "An Integrated and Reliable Workflow to Determine Critical Rates for Gas and Water Coning in Oil and Gas Reservoirs - A Multi Well Approach, Case Study Pemex, Mexico". In SPE Trinidad and Tobago Section Energy Resources Conference. Society of Petroleum Engineers, 2016. http://dx.doi.org/10.2118/180775-ms.

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