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Machine learning for recovery factor estimation of an oil reservoir:A tool for derisking at a hydrocarbon asset evaluation

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Petroleum 2022年第2期8卷 278-290页

作者： Ivan Makhotin Denis Orlov Dmitry Koroteev Evgeny Burnaev Aram Karapetyan Dmitry Antonenko Skolkovo Institute of Science and Technology MoscowRussia JSC Zarubezhneft MoscowRussia

Well-known oil recovery factor estimation techniques such as analogy,volumetric calculations,material balance,decline curve analysis,hydrodynamic simulations have certain limitations.Those techniques are time-consuming,and require specific data and expert knowledge.Besides,though uncertainty estimation is highly desirable for this problem,the methods above do not include this by default.In this work,we present a data-driven technique for oil recovery factor(limited to water flooding)estimation using reservoir parameters and representative statistics.We apply advanced machine learning methods to historical worldwide oilfields datasets(more than 2000 oil reservoirs).The data-driven model might be used as a general tool for rapid and completely objective estimation of the oil recovery factor.In addition,it includes the ability to work with partial input data and to estimate the prediction interval of the oil recovery factor.We perform the evaluation in terms of accuracy and prediction intervals coverage for several tree-based machine learning techniques in application to the following two cases:(1)using parameters only related to geometry,geology,transport,storage and fluid properties,(2)using an extended set of parameters including development and production data.For both cases,the model proved itself to be robust and reliable.We conclude that the proposed data-driven approach overcomes several limitations of the traditional methods and is suitable for rapid,reliable and objective estimation of oil recovery factor for hydrocarbon reservoir.

关键词： oil recovery factor Machine learning Regression Uncertainty estimation Conformal predictors Clustering oilfield oil reservoir

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Unlocking the potentials of gel conformance for water shutoff in fractured reservoirs: Favorable attributes of the double network gel for enhancing oil recovery

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Petroleum Science 2023年第2期20卷 1005-1017页

作者： Qian-Hui Wu Ji-Jiang Ge Lei Ding Gui-Cai Zhang School of Petroleum Engineering China University of Petroleum(East China)Qingdao266580ShandongPR China Laboratoire Sciences et Ingénierie de la Matière Molle ESPCI ParisPSL University75005ParisFrance Total Energies SE. E&PPôle d’Etudes et Recherche de LacqBP 47LACQ64170France

The double-network prepared with an in-situ monomer gel and a fast-crosslinked Cr(III) gel is introduced to develop a thixotropic and high-strength gel (THSG), which is found to have many advantages over the traditional gels. The THSG gel demonstrates remarkable thermal stability, and no syneresis is observed after 12 months with high salinity brine (95,500 mg/L). Moreover, the SEM and XRD results indicate that the gel is intercalated into the lamellar structures of Na-MMT, where the gel can form a uniform and compact structure. In addition, the THSG gel has an excellent swelling behavior, even in the high salinity brine. In the slim tube experiments, the THSG gel exhibits high rupture pressure and improves blocking capacity after being ruptured. The core flooding results show that a layer of gel filter cake is formed on the face of the fracture, which may be promoted by a high matrix permeability, a small aperture fracture, and a high injection rate. After the gel treatment, the fracture can be completely blocked by the THSG gel. It is found that a high incremental oil recovery (65.3%) can be achieved when the fracture was completely blocked, compared to 40.2% if the gel is ruptured. Although the swelling of ruptured gel can improve oil recovery, part of the injected brine may be channeled through the gel-filled fractures, resulting in a decrease in the sweep efficiency. Therefore, the improved blocking ability by gel swelling (e.g., in fresh water) may be less efficient to contribute to an enhancement of oil recovery. It is also found that the pressure gradient and residual resistance factor to water (Frrw) are higher if the matrix is less permeable, indicating that the fractured reservoir with lower matrix permeability may require a higher gel strength for treatment. The findings of this study may provide novel insights on designing robust double network gels for water shutoff in fractured reservoirs.

关键词： Double network structure Gel swelling Rupture pressure Fractured core oil recovery factor

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Simulation studies on optimizing oil productivity in oil rim reservoirs under gas cap blow down production strategy

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Petroleum 2023年第3期9卷 373-389页

作者： Oluwasanmi Olabode Pelumi Adewunmi Odera Uzodinma Gideon Famurewa Princess Ogba Chukwuemeka Amah Department of Petroleum Engineering Covenant UniversityOgun StateNigeria

Gas cap blow down strategy is normally deployed for Ultra-thin oil rim reservoirs with huge gas caps due to extremely high gas oil ratios from wells in such reservoirs.The current state leads to loss of production from the oil reserves due to high initial reservoir pressure thus,reducing its net present value.Data on important factors essential to the productivity of oil rim reservoirs are used to build a heterogeneous ultra-thin reservoir with a time step of 10,000 days using the Eclipse software and its embedded correlations.The reservoir is subjected to a gas cap blowdown via a gas well,then an oil well is initiated into the model at onset and after time periods of 2000 days,4000 days,6000 days and 8000 days to estimate the oil recovery.It is expected that due to the large nature of the gas cap,pressure decline will be drastic and leading to a low oil recovery,hence the injection of water and gas at different rates at the periods indicated.The results indicate an oil recovery of 4.3%during gas cap blow down and 10.34%at 6000 days.Peak oil recoveries of 12.64%and 10.80%are estimated under 30,000 Mscf/day at 4000 days and 1000 stb/day at 6000 days respectively.This shows an incremental oil recovery of 8.34%and 6.5%over that recorded during gas cap blow down.The results also indicate that the gas production at those periods was not greatly affected with an estimated increment of 257 Bscf recorded during 30,000 Mscf/day at 4000 days.All secondary injection schemes at the respective time steps had positive impact on the overall oil recoveries.It is recommended that extra production and injection wells be drilled,enhanced oil recovery options and injection patterns be considered to further increase oil recovery.

关键词： oil rim Gas cap blow down Water and gas injection oil recovery factor

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Simulation of low and high salinity water injection method to determine the optimum salinity

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Petroleum Research 2019年第4期4卷 348-353页

作者： Seyed Mohammad Mehdi Nassabeh Afshin Davarpanah Joata Bayrami Department of Petroleum Engineering Faculty of Engineering and TechnologyOmidiyeh BranchIslamic Azad UniversityOmidiyehIran Department of Petroleum Engineering Science and Research BranchIslamic Azad UniversityTehranIran

Investigating the enhanced oil recovery leads to optimal production,protection and reduction of lateral impacts.Low salinity water injection(LSWI)is one of the significantly improved oil recovery(IOR)techniques for changing the amount of wettability in the carbonate fractured reservoirs.The utilization of this methodology in terms of high efficiency in displacing light crude oils to the medium-gravity crude oils,water sources availability and its sustainability for pushing the oil which leads to appropriate economic occasions,are being compared with other IOR/EOR techniques.In this study,the best injection modelling pattern is based on the highest rate of recovery factor.Comparison of“high and low salinity water injection method”with“pure water injection method”is performed in an oil reservoir.Overall,analyzing the sensitivity on the high and low salinity according to the moderately low recovery factor of high and low salinity among the injection scenarios illustrates the low sensitivity of this parameter on a fractured carbonate reservoir.By reviewing different scenarios,it could be demonstrated that if the water injection could be applied to the reservoir from the preliminary times of production,the recovery factor rate would be increased.Thereby,higher appropriate efficiency and better supplement have resulted.Pure water injection has a high recovery factor than salty water injection.By the way,these two methods have little differences in calculating recovery methods.Besides,this parameter is significantly depended on wellhead equipment properties,safety factor and economic issues(water production).

关键词： Low salinity water injection Enhance oil recovery Injection scenarios oil recovery factor Water production

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A simulation study of water injection and gas injectivity scenarios in a fractured carbonate reservoir:A comparative study

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Petroleum Research 2019年第3期4卷 250-256页

作者： Afshin Davarpanah Behnam Mirshekari A.Armin Razmjoo Department of Petroleum Engineering Science and Research BranchIslamic Azad UniversityTehranIran Escolla Tecnica Superior d'Enginyeria Industrial de Barcelona(ETSEIB) Universitat Politecnica de Catalunya(UPC)Av.Diagonal64708028BarcelonaSpain

Regarding the enormous demands of numerous industries to fossil fuels,it is essential to select the proper enhanced oil recovery approaches for vertical and horizontal wells to supply the demands with the optimum expenditure.Water and gas injectivity as the secondary enhanced oil recovery techniques would be preferentially considered regarding their low costs of performances rather than chemical recovery and thermal techniques.Injected gas tends to push oil through pores or cracks in the matrix block and lead them to the production well.Therefore,injection of gas may significantly increase the recovery factor in these reservoirs.In this research,different injection scenarios in a fractured carbonate reservoir in the west of Iran are being simulated by the PVT modules of Eclipse software.The purpose of this research is to analyze the possibility of gradually increasing the extent of recovery by injecting carbon dioxide,methane,and water,and different injectivity patterns are considered in this research.The selection of injectivity patterns is severely based on the highest recycling rate of gas injection on different injection scenarios,and the injectivity scenarios were being compared with the natural depletion scenario.Consequently,Co2 injection(about 60%)had the highest oil recovery factor and CH4 and TB(about 54%and 53%)injectivity scenarios had the second and third highest rate of the oil recovery factor.

关键词： Fractured carbonated reservoir Gas injection scenarios Co2 injection oil recovery factor Injectivity patterns

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Experimental investigation on continuous N_(2) injection to improve light oil recovery in multi-wells fractured-cavity unit

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Petroleum 2017年第3期3卷 367-376页

作者： Wei Su Jirui Hou Teng Zhao Yuanyuan Xi Can Cui Institute of Enhanced oil recovery China University of Petroleum(Beijing)BeijingChina Tarim oilfield Prospecting and Development Research Institute China National Petroleum CorporationXinjiangChina

The purpose of this experimental study is to evaluate the feasibility and oil recovery efficiency of continuous N_(2) injection in a multi-well fractured-cavity reservoir.In this study,the similar criterion of physical simulation was firstly discussed.In order to reveal the mechanism of remaining oil startup and production performance characteristic by continuous N_(2) injection,a visualized twodimensional fractured-cavity model and a three-dimensional pressure resistant model were designed and fabricated respectively based on the similar theory.And the 2D visualized physical experiments and 3D physical experiments were performed with the simulated oil and brine reservoir samples in Tahe oilfield.Four groups of experiments in 2D and 3D model were performed,each of which included bottom water depletion driving,water injection and N_(2) injection.The 2D visualized experiments indicated the main mechanism of N_(2) developing remaining oil was to occupy the high position and replace the attic oil due to gravitational differentiation.Furthermore,both the 2D and 3D experiments demonstrated that higher oil recovery factor could be achieved if N_(2) was injected through high positional wells.The 3D physical model is closer to the real reservoir condition,so the production performance can reflect the real field production process.This paper confirmed the efficiency of continuous N2 flooding in the light oil saturated fractured-cavity reservoir.

关键词： Continuous N_(2)injection Similar criterion 2D visualized model 3D pressure resistant model oil recovery factor

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EXPERIMENTAL STUDIES ON WATER-FLOODING PROCESS UNDER VIBRATING STIMULATIONS

EXPERIMENTAL STUDIES ON WATER-FLOODING PROCESS UNDER VIBRATI...

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The Second International Conference on Dynamics Vibration and Control

作者： Renyuan Sun School of Petroleum Engineering China University of Petroleum Dongying 257061 China

＜正＞A new system for the simulation of artificial vibration oil production （AVOP） was designed. The water-flooding process under vibrating stimulation with different frequency and amplitude were conducted on the system. The cores used were man-made cores and the oil was simulated oil. The vibrating stimulation were conducted in the whole process, in the stage of high water-cut and periodic

关键词： artificial vibration artificial vibration oil production（AVOP） oil recovery factor water cut enhanced oil recovery（EOR）

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