Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 A New Method for Predicting Well Pattern Connectivity in a Continental Fluvial-delta Reservoir 3 12 807 10.22078/jpst.2017.807 EN Yanfeng Liu China University of Petroleum(Beijing) Yuetian Liu China University of Petroleum(Beijing) Lu Sun China University of Petroleum(Beijing) Jian Liu PetroChina Research Institute of Petroleum Exploration and Development Journal Article 2015 09 08 The features of bad flow unit continuity and multiple layers emphesize the importance of a well pattern design for the development of a fluvial-delta reservoir. It is proposed a method to predict well pattern connectivity (WPC) based on the exploration and evaluation of wells. Moreover, the method helps evaluate the risk of well placement. This study initially establishes the parameters for characterizing the lateral and vertical flow unit distributions. Then, extensive statistics on the mature oil-field sands of synthetic geological models are obtained to generate the prediction model of WPC which will reveal the correlation among WPC, flow unit distribution, and well spacing (WS). Finally, a case study is conducted to validate the proposed method for predicting WPC. The procedure of the method is comprised of two steps. The first step is to calculate the parameters which characterize the vertical sand body distribution of the target formation by using the well drilling and logging information. The second step is to integrate the calculated parameters and designed WS into the proposed formula to forecast WPC. The new method of WPC prediction has the advantage of integrating the static and dynamic information of similar mature oil fields with each other. By utilizing the model, making an important decision on well pattern design and a reservoir production forecast in the newly discovered continental fluvial-delta reservoir would be reasonable. https://jpst.ripi.ir/article_807_6e7b33fdea3adc80ebd648fffb665bb8.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 An Injection Rate Optimization in a Water Flooding Case Study with an Adaptive Simulated Annealing Techniques 13 31 813 10.22078/jpst.2017.1974.1350 EN Vahid Azamipour Thermodynamics Research Laboratory, School of Chemical Engineering, Iran University of Science and Technology, Tehran 16846-13114, Iran Mehdi Assareh Thermodynamics Research Laboratory, School of Chemical Engineering, Iran University of Science and Technology, Tehran 16846-13114, Iran Journal Article 2016 04 17 This paper introduces an effective production optimization and a water injection allocation method for oil reservoirs with water injection. In this method, a two-stage adaptive simulated annealing (ASA) is used. A coarse-grid model is made based on average horizon permeability at the beginning iterations of the optimization to search quickly. In the second stage, the fine-grid model is used to provide the accuracy of the final solution. A constrained optimization problem to maximize an objective function based on net present value is implemented. Allocation factors from the streamline simulation are used to help for the appropriate estimation of initial water injection rates. The proposed optimization scheme is used for a field sector simulation model. The results show that the optimized rates confirm the increment of total oil production. Optimized oil production and total water injection rates lead to an increase in the total oil production from 385.983 (initial guess) to 440.656 Msm³. This means a recovery factor increment by 14.16%, while the initial rates were much higher than the optimized rates. Moreover, the recovery factor of optimized production schedule with an optimized total injection rate is 2.20% higher than the initial production schedule with an optimized total water injection rate. The allocation of the water injection rates and the revision of allocation rates result in 446.383 and 450.164 Msm³. The revision of the water rates allocation provides a reduction of water cut during production. https://jpst.ripi.ir/article_813_e0cf1f47118daebc5b16269099ad7347.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 A New Discovery about Inflow Control Devices in Controlling Water and Increasing Oil Recovery 32 40 808 10.22078/jpst.2017.808 EN Mingjun Li Correspond author Ma Yongxin CNOOC -Ltd Zhanjiang. Zhanjiang, 524057, Zhanjiang, China Yi Xiangyi Chengdu University of Technology; Chengdu, 610059, Chengdu, China Journal Article 2015 10 01 Inflow control devices (ICD), which prevent water breakthrough by controlling the inflow profile of a well, have been used successfully in many oilfields. This paper will introduce a new discovery and an unsuccessful example. Moreover, this paper investigates meticulously and thoroughly to find the application conditions of the new discovery. Based on permeability rush coefficient and permeability differential, a series of plans are carried out to study ICD application conditions. Finally, a new discovery is developed. There are inflow-control device applications for ICD’s, which can work well in heterogeneous reservoirs for controlling water and increasing oil production, but they cannot work well in a homogeneous formation. The effect of ICD on controlling water and increasing oil is very sensitive to the degree of reservoir heterogeneity. The cumulative oil production increases with increasing permeability rush coefficient and permeability differential. https://jpst.ripi.ir/article_808_a8ecbabae151abacba7dbde04f761c37.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 Mathematical Modeling of Carbon Dioxide Removal from the CO2/CH4 Gas Mixture Using Amines and Blend of Amines in Polypropylene: A Comparison between Hollow Fiber Membrane Contactor and Other Membranes 41 53 811 10.22078/jpst.2017.1993.1354 EN Mohammad Reza Talaghat Shiraz university of technology Ahmad Reza Bahmani Shiraz university of technology Journal Article 2016 05 02 In this work, a mathematical model is established to describe the removal of CO₂ from gaseous mixtures including CH₄ and CO₂ in a polypropylene hollow fiber membrane contactor in the presence of conventional absorbents such as monoethanolamine (MEA), methyldiethanolamine (MDEA), and a blend of them. Modeling was performed in axial and radial directions under the fully-wet condition for countercurrent gas-liquid flow arrangement. Both of axial and radial diffusions have been considered in three segments, including shell, membrane, and tube. To evaluate the model, the results of this model were compared with the experimental data and the results of COMSOL software and the results were in agreement with the experimental data and COMSOL outputs. In addition, the effect of various parameters on the removal percentage of carbon dioxide from gas mixtures was studied. It was found out that the CO₂ removal percentage is the best by using MEA solution as the absorbent. This modeling shows that the removal of CO₂increases by adding MEA into MDEA solution. In this study, the factors that influence the removal percentage of CO₂ from gaseous mixture were investigated. The CO₂ removal efficiency increased with an increase in the liquid flow rate, number of fibers, membrane length, porosity-to-tortuosity ratio, and solvent concentration. The results show that increasing gas flow rate reduces CO₂removal due to decreasing the contact time. Finally, the performance of this membrane was compared with other membranes such as polyvinyl difluoride (PVDF) and polytetrafluoroethylene (PTFE). The results show that the percentage of CO₂ removal by the polypropylene HFM is higher than that of the PVDF and PTFE hollow fiber membranes in the presence of MEA as the absorbent. https://jpst.ripi.ir/article_811_670e8a43b246801ca1eaca97b3e19189.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 A Nonlinear Creep-damage Constitutive Model of Mudstone Based on the Fractional Calculus Theory 54 64 809 10.22078/jpst.2017.809 EN Zhang Jun Northeast Petroleum University Zeng Jia Northeast Petroleum University Journal Article 2015 10 10 During the flood development in an oil field, the creep characteristic of mudstone is one of the important factors causing casing damage. In this study, based on the theory of fractional order differential and taking into account the creep damage evolution rules, a fractional nonlinear creep-damage model is proposed to reflect the instantaneous deformation in loading processes and the accelerated creep stage of mudstone. After assuming that the relationships between strain and time can be expressed by the exponential functions, the creep-damage constitutive model to describe the relationship between stress and strain stress of mudstone is established under the condition of accelerated strain rate loading. Furthermore, uniaxial creep tests and conventional triaxial compression tests were carried out to validate the proposed model. It is found that the fractional nonlinear creep-damage model can effectively describe the characteristics of the three stages of mudstone creep; moreover, this model can reduce the number of components and the parameters. Both the fractional nonlinear creep model and the creep-damage constitutive model have a high fitting relationship with the test results. Also, the initial elastic modulus and confining pressure are in a good linear relationship. Finally, the parametric sensitivity analysis of the theoretical model is carried out. The correctness and applicability of models were confirmed from three respects of the derivation process, test results, and the theoretical analysis. https://jpst.ripi.ir/article_809_32b30a250abd6331e03a2a1f16466346.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 An Experimental Investigation of Magnetized Water Effect on Formation Damage 65 76 812 10.22078/jpst.2017.2448.1419 EN Ehsan Khamehchi Amirkabir University of Technology Seyed Arman Hosseini Kaldozakh Amirkabir university of Technology Ali Alizadeh Amirkabir University of Technology Journal Article 2016 12 26 In oil industries, water injection into oil reservoirs for pressure maintenance, oil displacement, and oil recovery is a common technique. Formation damage during water injection is a major problem in this process. Formation damage from the incompatibility of formation water (FW) and injection water (IW) causes a reduction in the permeability around the injection wells. Therefore, it is necessary that the formation damage be minimized using specific techniques such as the injection of scale inhibitors and water compatible with formation water. It has been proven that moving water through relatively weak magnetic field changes water properties. These changes involve density, electrical conductivity, salts dissolving ability, sedimentation rate of solid particles etc. This study was conducted to investigate the effect of magnetized water injection on the decline in rock permeability. Therefore, a magnetic field device was designed and combined with a formation damage setup. The results indicate that, in the presence of magnetic field, water injection causes less damage to rock, and the permeability reduction in this case is lower than when non-magnetized water is injected. In addition, the results show that a higher magnetic field flux reduces the permeability damage. https://jpst.ripi.ir/article_812_81e74d678581a3bb7a720b019f4f1a93.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 An Experimental Investigation of Feasibility of Gas Huff and Puff for Recovering Crude Oil with Different Viscosities 77 90 810 10.22078/jpst.2017.810 EN Jiang Ping China University of Petroleum (East China) Zhang Lei China University of Petroleum (East China) Ge Jijiang China University of Petroleum (East China) Zhang Guicai China Universit of Petroleum (East China) Yuan Yufeng China Petroleum & Chemical Corporation Wang Yang China University of Petroleum (East China) Pei Haihua China University of Petroleum (East China) Journal Article 2015 11 21 Investigating multi cyclic gas (N₂ and CO₂) huff and puff have been conducted by long sandpack simulations with four different crude oils from Jiangsu oilfield. According to the production differential pressure and the production regularity during huff and puff, the production process was divided into three sections; the first one is free gas production section; the second section is low viscous oil production section, and the third one is gas driving exploitation section. According to the results, the production decreases with the increase of cycle times at a certain backpressure, and the effect of multi-cycle huff and puff is improved as the backpressure decreases. In the same cycle, the oil production increases as the backpressure declines. In the first huff and puff cycle, positive synergistic effects are generated while CO₂ and N₂are being mixed, and there is an optimum ratio between them. The amount of CO₂in the optimum ratio increases as the backpressure rises. The effect of single gas is better than that of mixed gas in multi-cycle huff and puff, and the effect of CO₂ is better than that of N₂. The effect of huff and puff is not influenced by the injection mode. At a high backpressure, the huff-and-puff effect becomes better as the oil viscosity increases, but at low backpressure, it becomes worse with an increase in oil viscosity. The huff-and-puff effect also gets worse as the temperature rises. The oil recovery degree is improved as the CO₂ injection amount increases, but there is an optimal oil exchange ratio. The depressurization process should be neither too quick nor too slow in the CO₂ huff-and-puff process. The cyclic oil production is improved with the increase of injection rate while the average injection rate is lower than 90 L/min. The equilibrium time of CO₂ is shorter than that of N₂. The economic return of N₂ huff and puff is better than that of CO₂ at high producing pressure drop, and light oil has higher economic returns than heavy oil. https://jpst.ripi.ir/article_810_b6edc1cd1f36e45daf6d7824d7bb2283.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 7 4 2017 11 15 A Mechanical Model and its Experimental Verification for a Water Injection String in a Highly Deviated Well 91 101 814 10.22078/jpst.2017.1811.1324 EN Liu Jun Laboratories equipped with modern design and simulation of oil and gas, Southwest Petroleum University, Cheng Du Si Chuan 610500, P.R. of China Wang Wei School of Civil and Architecture Engineering, Southwest Petroleum University, Cheng Du Si Chuan 610500, P.R. of China Liu Qing You Laboratories equipped with modern design and simulation of oil and gas, Southwest Petroleum University, Cheng Du Si Chuan 610500, P.R. of China Zhang Jian Zhong Drilling technology research institute of Jidong oilfield company, Tang Shan He Bei 063000, P.R. of China Xiao Guo Hua Drilling technology research institute of Jidong oilfield company, Tang Shan He Bei 063000, P.R. of China Sang Guo School of Civil and Architecture Engineering, Southwest Petroleum University, Cheng Du Si Chuan 610500, P.R. of China Journal Article 2016 01 09 Water injection strings in highly deviated wells are subjected to complex forces on the string bore. In this work, a mechanical model is developed for these forces and for those on downhole tools. On the basis of this model, and taking account of the characteristics of the string in different working conditions, a temperature field model and a pressure field model are introduced, and a statically indeterminate structural calculation method is adopted. A force tester for highly deviated wells is developed and used in eight tests on strings in the Jidong Nanpu oilfield making a comparison between the measurements from the tests and the results of calculations using the mechanical model indicates that the mechanical model exhibits high computational accuracy, with the errors at the wellhead being no more than 10%, and that the forces on packers calculated from the model are in accordance with those measured in the tests. Thus, the mechanical model developed in this work is suitable for analyzing the forces on water injection strings and downhole tools in highly deviated wells. https://jpst.ripi.ir/article_814_96b9bff013acedfb1d140579e2fbeb63.pdf