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Subsection and superposition method for reservoir formation damage evaluation of complex-structure wells

Petroleum Science 2023年第3期20卷 1843-1856页

作者： Guan-Cheng Jiang Yi-Zheng Li Yin-Bo He Teng-Fei Dong Ke-Ming Sheng Zhe Sun Collge of Petroleum Engineering China University of Petroleum(Beijing)Bejing102249China State Key Laboratory of Petroleum Resources and Prospecting MOE Key Laboratory of Petroleum EngineeringChina Universityof Petroleum(Beijing)Beijing102249China College of Artificial Intelligence China University of Petroleum(Bejing)Beijing102249China Calgary Centre for Innovative Technology University of CalgaryCalgaryAB T2N 1N4Canada National Engineering Research Center of Oil&Gas Drilling and Completion Technology

Kinds of complex-structure wells can effectively improve production,which are widely used.However,in the process of drilling and completion,complex-structure wells with long drilling cycle and large exposed area of reservoir can lead to the fact that reservoir near wellbore is more vulnerable to the working fluid invasion,resulting in more serious formation damage.In order to quantitatively describe the reservoir formation damage in the construction of complex-structure well,taking the inclined well section as the research object,the coordinate transformation method and conformal transformation method are given according to the flow characteristics of reservoir near wellbore in anisotropic reservoir.Then the local skin factor in orthogonal plane of wellbore is deduced.Considering the un-even distribution of local skin factor along the wellbore,the oscillation decreasing model and empirical equation model of damage zone radius distribution along the wellbore direction are established and then the total skin factor model of the whole well is superimposed to realize the reservoir damage evaluation of complex-structure wells.Combining the skin factor model with the production model,the production of complex-structure wells can be predicted more accurately.The two field application cases show that the accuracy of the model can be more than 90%,which can also fully reflect the invasion characteristics of drilling and completion fluid in any well section of complex-structure wells in anisotropic reservoir,so as to further provide guidance for the scientific establish-ment of reservoir production system.

关键词： Complex-structure wells Reservoir formation damage Reservoir anisotropy skin factor Production prediction model

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Maximizing the Benefit of Rate Transient Analysis for Gas Condensate Reservoirs

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Energy Engineering 2021年第5期118卷 1411-1423页

作者： Mahmoud Abdo Tantawy Ahmed A.M.Elgibaly Ahmed Mohamed Farag Faculty of Petroleum and Mining Engineering Suez UniversitySuezEgypt Abu Qir Petroleum Company AlexandriaEgypt

In recent years,many trials have been made to use the Rate Transient Analysis(RTA)techniques as a method to describe the gas condensate reservoirs.The problem with using these techniques is the multi-phase behavior of the gas condensate reservoirs.Therefore,the Pressure Transient Analysis(PTA)is commonly used in this case to analyze the reservoir parameters.In this paper,we are going to compare the results of both PTA and RTA of three wells in gas condensate reservoirs.The comparison showed a great match between the results of the two mentioned techniques for the first time using a reference GOR of 75,000 SCF/STB.Therefore,we concluded that we could depend on RTA instead of PTA to spare the cost associated with the PTA in the gas condensate reservoirs.

关键词： Rate transient analysis production data analysis well testing permeability skin factor gas condensate

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Determination of oil well production performance using artificial neural network (ANN) linked to the particle swarm optimization (PSO) tool

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Petroleum 2015年第2期1卷 118-132页

作者： Mohammad Ali Ahmadi Reza Soleimani Moonyong Lee Tomoaki Kashiwao Alireza Bahadori Department of Petroleum Engineering Ahwaz Faculty of Petroleum EngineeringPetroleum University of TechnologyAhwazIran Young Researchers and Elite Club Neyshabur BranchIslamic Azad UniversityNeyshaburIran School of Chemical Engineering Yeungnam UniversityGyeungsanRepublic of Korea Department of Electronics and Control Engineering National Institute of TechnologyNiihama College7-1 Yagumo-choNiihamaEhime 792-8580Japan School of Environment Science&EngineeringSouthern Cross UniversityLismoreNSWAustralia

Greater complexity is involved in the transient pressure analysis of horizontal oil wells in contrast to vertical wells,as the horizontal wells are considered entirely horizontal and parallel with the top and underneath boundaries of the oil reserve.Therefore,there is an essential need to estimate productivity of horizontal wells accurately to examine the effectiveness of a horizontal well in terms of technical and economic prospects.In this work,novel and rigorous methods based on two different types of intelligent approaches including the artificial neural network(ANN)linked to the particle swarm optimization(PSO)tool are developed to precisely forecast the productivity of horizontal wells under pseudo-steady-state conditions.It was found that there is very good match between the modeling output and the real data taken from the literature,so that a very low average absolute error percentage is attained(e.g.,<0.82%).The developed techniques can be also incorporated in the numerical reservoir simulation packages for the purpose of accuracy improvement as well as better parametric sensitivity analysis.

关键词： Well productivity Drainage area skin factor Least square Support vector machine Hybrid connectionist model Particle swarm optimization

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Analytical models & type-curve matching techniques for reservoir characterization using wellbore storage dominated flow regime

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Petroleum 2018年第2期4卷 223-239页

作者： Salam Al-Rbeawi METU-Northern Cyprus Campus Cyprus

The applicability of early time data in reservoir characterization is not always considered worthy.Early time data is usually controlled by wellbore storage effect.This effect may last for pseudo-radial flow or even boundary dominated flow.Eliminating this effect is an option for restoring real data.Using the data with this effect is another option that could be used successfully for reservoir characterization.This paper introduces new techniques for restoring disrupted data by wellbore storage at early time production.The proposed techniques are applicable for reservoirs depleted by horizontal wells and hydraulic fractures.Several analytical models describe early time data,controlled by wellbore storage effect,have been generated for both horizontal wells and horizontal wells intersecting multiple hydraulic fractures.The relationships of the peak points(humps)with the pressure,pressure derivative and production time have been mathematically formulated in this study for different wellbore storage coefficients.For horizontal wells,a complete set of type curves has been included for different wellbore lengths,skin factors and wellbore storage coefficients.Another complete set of type curves has been established for fractured formations based on the number of hydraulic fractures,spacing between fractures,and wellbore storage coefficient.The study has shown that early radial flow for short to moderate horizontal wells is the most affected by wellbore storage while for long horizontal wells;early linear flow is the most affected flow regime by wellbore storage effect.The study has also emphasized the applicability of early time data for characterizing the formations even though they could be controlled by wellbore storage effect.As a matter of fact,this paper has found out that wellbore storage dominated flow could have remarkable relationships with the other flow regimes might be developed during the entire production times.These relationships can be used to properly describe the formations and quantify some of their

关键词： Reservoir engineering Reservoir modeling and simulation Pressure transient analysis Reservoir characterization Wellbore storage effect skin factor Reservoir flow regimes Pressure behaviors

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Cross-flow analysis of injection wells in a multilayered reservoir

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Petroleum 2016年第3期2卷 273-281页

作者： Mohammadreza Jalali Jean-Michel Embry Francesco Sanfilippo Frederic J.Santarelli Maurice B.Dusseault Geological Institute ETH ZurichZurichSwitzerland Baker Hughes AberdeenUnited Kingdom Geomec Environmental Management AS StavangerNorway Earth&Environmental Sciences Department University of WaterlooWaterlooONCanada

During fluid injection into a multilayered reservoir,a different pressure gradient is generated across the face of each permeable layer.This pressure gradient generates driving forces in the wellbore during well shut-in that causes the injected fluid moves from higher pressure layers to lower pressure layers,a phenomenon known as interwell cross-flow.Cross-flow behavior depends on the initial pressure in the permeable layers and may be referred to as natural cross-flow(identical or natural initial pressures)and forced cross-flow(different initial pressures because of exploitation).Cross-flow may induce sand production and liquefaction in the higher pressure layers as well as formation damage,filter cake build-up and permeability reduction in the lower pressure layers.Thus,understanding cross-flow during well shut-in is important from a production and reservoir engineering perspective,particularly in unconsolidated or poorly consolidated sandstone reservoirs.Natural and forced cross-flow is modeled for some injection wells in an oil reservoir located at North Sea.The solution uses a transient implicit finite difference approach for multiple sand layers with different permeabilities separated by impermeable shale layers.Natural and forced cross-flow rates for each reservoir layer during shut-in are calculated and compared with different production logging tool(PLT)measurements.It appears that forced cross-flow is usually more prolonged and subject to a higher flow rate when compared with natural cross-flow,and is thus worthy of more detailed analysis.

关键词： Cross-flow Multilayered Sandstone reservoir Sand production skin factor

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