Download or read book An Investigation Into the Effect of Gas Injection on Oil Recovery Using Numerical Simulation written by Abudlhakem A. Harati and published by . This book was released on 1992 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical simulation of gas injection in oil reservoirs written by Rolf Halvor Utseth and published by . This book was released on 1980 with total page 342 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical Simulation of Gas Injection for Upstructure Drainage written by Richard F. Strickland and published by . This book was released on 1976 with total page 148 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Co2 assisted Gravity Drainage EOR written by Prashant Sopanrao Jadhawar and published by . This book was released on 2010 with total page 524 pages. Available in PDF, EPUB and Kindle. Book excerpt: Increasing demand of the oil and gas have given rise to surge in drilling and exploration activities to recover oil from other unexplored oil-bearing formations (such as offshore) as well as in the efforts to improve and/or modify the existing methods of the enhanced oil recovery to recover the residual oil left-behind by the applied EOR method. Nearly one-third volume of the original oil in place (OOIP) is left-behind by the current EOR technologies. Estimated 2 trillion barrels of this volume is lucrative to cater the energy needs of the respective countries. Gas injection EOR method is a major contending process in exploitation of this resource, and its application is on the rise since last decade. Continuous gas injection (CGI) and water-alternating gas (WAG) injection are the most notable and commonly field-implemented horizontal displacement type gas injection EOR processes. The limitations of CGI are the severe gravity segregation and poor sweep efficiencies. Although the reservoir sweep efficiencies are improved with the WAG, review of 59 field projects suggest that they yield only maximum of 10% incremental oil recoveries due to the detrimental effects of increased water saturation to diminish gas injectivity, reducing oil mobility, decreased oil relative permeability and oil bypassing due to gravity segregation. Conversely, vertical downward oil-displacement gas driven gravity drainage EOR methods uses the gravity forces to its advantage for enhancing the oil recovery. Gravity drainage EOR methods have been applied to dipping and reef type reservoirs in the field projects and reported to yield high incremental oil recoveries. In this study, the CO2-assisted gravity drainage EOR method is investigated in the non-dipping reservoir through the 3D reservoir simulations and scaling and the sensitivity analysis. Both the compositional and pseudomiscible black-oil numerical reservoir simulations are conducted in the 50 and 35 °API gravity oil-reservoirs respectively. Main objectives of this research are to (i) develop a better production strategy for the oil recovery optimization (ii) investigate the options to optimize oil recovery in the CO2-assisted gravity drainage EOR process (numerical simulation studies) (iii) to develop a set of scaled models sufficient to completely scale the CO2-assisted gravity drainage EOR process through the scaling and sensitivity studies. Original contributions of this research are (i) First comprehensive demonstration of the CO2-assisted gravity drainage EOR method application in 50 °API gravity oil-reservoir, (ii) Development and verification of a new hypothesis of the horizontal gas floodfront in the top-down CO2-assisted gravity drainage EOR process, (iii) Development of a general process selection map for the preliminary choice between the immiscible and miscible process, (iv) Grid size effect studies: Changes in both the x and y grid-dimensions has no impact on the CO2-assisted gravity drainage oil recovery, (v) Grid thickness effect studies: Thin layers, even in the upper layers, facilitates the optimum CO2-assisted gravity drainage oil recovery (vi) Heterogeneity in permeability effect: Presence of heterogeneity in permeability (kv / kv = 0.001) improves the CO2-assisted gravity drainage oil recovery performance (95.5% incremental oil recovery) thereby reducing the number of pore volumes and the operational time. It has been found that recovery further improves when the molecular diffusion effects are taken into account, (vii) Heterogeneity in porosity: Porosity values increasing downwards, such as in the overturned faults, promotes the CO2-assisted gravity drainage mechanism to yield better oil recovery performance, (viii) Clear identification of the overall mechanisms and the supporting micro-mechanisms through the parametric analysis of the reservoir simulation results, (ix) Development of a new correlation (combination number, NJadhawar and Sarma) that encompasses the traditional process affecting multiphase operational parameters in the form of the dimensionless groups. It is further validated using the field projects including the data from the Oseberg field, Norway. Excellent logarithmic correlation match is obtained between the new combination number, NJadhawar and Sarma, and the oil recoveries from both the immiscible and miscible reservoir simulations as well as the field projects. New combination number, NJadhawar and Sarma, is a useful tool to predict CO2-assisted gravity drainage oil recoveries, and (x) Development of a set of the additional scaled models sufficient to completely scale the CO2-assisted gravity drainage EOR process are proposed and validated.

Download or read book Numerical Simulation in Oil Recovery written by Mary E Wheeler and published by . This book was released on 1987-12-08 with total page 300 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Prediction of Gas Injection Performance for Heterogenous Reservoirs Semi annual Technical Report October 1 1996 March 31 1997 written by and published by . This book was released on 1997 with total page 11 pages. Available in PDF, EPUB and Kindle. Book excerpt: The current project is a systematic research effort that will lead to a new generation of predictive tools for gas injection processes in heterogeneous reservoirs. The project is aimed at quantifying the impact of heterogeneity on oil recovery from pore level to reservoir scales. This research effort is, therefore, divided into four areas: (1) Laboratory Gas Injection Experiments (2) Network Modeling of Three-Phase Flow (3) Benchmark Simulation of Gas Injection Processes (4) Streamline Simulator Development. The status of the research effort in each area is reviewed briefly in the following section. Project Status Laboratory Gas Injection Experiments Gravity drainage of oil in the presence of gas and water has found to result in high recovery efficiency. Numerical representation of the high recovery efficiency requires a good understanding of three-phase relative permeabilities, especially at low oil saturations. Ph. D student Akshay Sahni has analyzed experimental results of selected three-phase displacements in the literature and compared them with the newly developed mathematical theory of three-phase flow in porous media. He approximated the relative permeability of each phase as a polynomial function of the saturation of that phase. An excellent agreement has been obtained between the measured and the calculated saturation paths. The analytical solution has also been checked by performing numerical simulations. Fig. 1 is an example of the comparisons of experiments, mathematical theory and numerical simulations. Fig. 1 shows a situation in which gas is injected into a system with high oil saturation and the formation of an oil bank is observed. The experiments in the literature were generally conducted at relatively high oil saturations. We have designed a series of gravity drainage experiments to measure three-phase relative permeability at low oil saturations. The CT scanner in the Petroleum Engineering Department at Stanford has been modified to measure in-situ saturations of vertically-placed samples, which is necessary in gravity drainage experiments. Akshay Sahni has finished a series of gravity drainage experiments in sand packs using different model oils to calibrate the scanner and to investigate the effect of spreading coefficient on three-phase relative permeability. A procedure has been developed for calculating relative permeabilities from measured in-situ saturations.

Download or read book Numerical Simulation Study written by Mahmod Mjahead Hwessa and published by . This book was released on 2009 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical Simulation in Oil Recovery written by Mary Fanett Wheeler and published by Springer. This book was released on 1988 with total page 304 pages. Available in PDF, EPUB and Kindle. Book excerpt: The papers of this book are based on a Symposium on Numerical Simulation in Oil Recovery held at the Institute for Mathematics and its Applications. The major research emphasis is on the modeling of fractures, heterogeneities, viscous fingering, and diffusion-dispersion effects in the flow in porous media. This volume contains seventeen comprehensive papers on the latest developments in this exciting subject. Its diverse presentation brings together the various disciplines of applied mathematics, chemical engineering, physics and hydrology.

Download or read book Numerical Simulation of Oil Recovery by Steam Injection written by Craig Irwin Beattie and published by . This book was released on 1980 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Study of Water and Carbonated Water Injection with Constant Pressure Boundaries written by Huan Yang and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The Buckley-Leverett theory for one-dimensional constant fluid velocity is widely used in the oil and gas industry. However, given a changing fluid velocity with fixed pressure boundary conditions, limitations arise. This work is based on an existing extension of the Buckley-Leverett theory in a water-oil system with fixed pressure boundary conditions. This allows the Buckley-Leverett theory to be applied to situations of injecting water at a constant bottom-hole pressure and producing oil at a fixed bottom-hole pressure. Based on mass conservation, numerical simulation is performed in Matlab® using the Implicit Pressure Explicit Satuation (IMPES) method for two-phase flow. The numerical solution is compared to the recently developed analytical solution for different case studies. The comparison is also used to illustrate the effect of numerical dispersion and round-off errors. This extension of the Buckley-Leverett theory has significant consequences in its applicability to more realistic operating scenarios and computational savings through analytical solutions. Carbonated water injection is studied numerically based on the validated water injection model. In carbonated water injection, CO2 is dissolved in water phase before injection. After injection, the properties of reservoir fluids will change due to the partitioning of CO2 between both the water and oil phases. Therefore, the reduction of oil viscosity and oil-water interfacial tension would be the main factors affecting the oil recovery. However, there is minimal research on carbonated water flooding combining both thermodynamics and reservoir simulation models. This research aims to study the effect for oil recovery in carbonated water injection based on both physical and numerical perspectives.

Download or read book Lab to Field Scale Modeling of Low Temperature Air Injection with Hydrocarbon Solvents for Heavy oil Recovery in Naturally Fractured Reservoirs written by Jose R. Mayorquin-Ruiz and published by . This book was released on 2015 with total page 197 pages. Available in PDF, EPUB and Kindle. Book excerpt: Alternatives for enhanced oil recovery processes in heavy oil containing deep naturally fractured reservoirs (NFR) are limited due to excessive heat losses when steam is injected. Air injection at high temperature oxidation conditions (in-situ combustion) has been considered as an alternative to aqueous based thermal applications. However, its implementation has serious limitations including poor areal distribution of injected air and poor combustion efficiency due to the heterogeneous nature of these reservoirs as well as the safety risk of unconsumed injected oxygen (O2) reaching the production wells. Taking advantage of the low cost and availability of air, one option is to use air at low temperature conditions (low temperature oxidation, LTO) as a pressurizing agent in NFR. Oxygenated compounds are generated at these conditions resulting in oil viscosity increase, reducing fluid mobility. In order to minimize this detrimental effect, a combination of air injection with hydrocarbon solvents can be applied. The objectives of this thesis are to evaluate air injection at LTO conditions in NFR containing heavy oil as a way to improve oil recovery, to clarify the effect of hydrocarbon solvent addition into air on oil recovery and O2 consumption, and to propose optimal conditions (temperature, air/solvent ratio) and implementation strategies for an efficient use of this suggested method. Comprehensive laboratory and numerical simulation studies were conducted to achieve these objectives. Static diffusion experiments--simulating cyclic gas injection (huff-and-puff)--were carried out by soaking heavy oil saturated cores into a reactor filled with gas representing a matrix/fracture system. Oil recovery and O2 consumption were the main parameters assessed and an extensive set of variables including rock type, temperature, fracture volume, solvent type, matrix size, gas injection sequences, and soaking times were studied. From experimental studies, the following conclusions were made: 1.Gas sequence design affects oil recovery, 2.O2 consumption in air cycles is higher after the core is soaked into butane rather than propane, 3.It is beneficial to soak cores in air+C3 mixture rather than pure air or solvent; i.e., lower O2 concentration in produced gas, less solvent usage, higher and faster oil recovery compared to alternate injection of air and C3. Then, core scale numerical simulation models were created for modeling lab experiments for a sensitivity analysis on Air/C3 ratio and matrix size. The results show that the process is extremely sensitive to matrix size and optimization of air injection (assisted by hydrocarbon solvents) can be achieved based on the minimized hydrocarbon solvent for a given matrix size. Additionally, a sensitivity analysis was performed using an up-scaled numerical model to the field scale containing meter-scale matrix blocks. It was observed that oil production mechanisms acting in a matrix block surrounded by gas filling the fractures are predominantly gas-oil gravity drainage, effective diffusion, and voidage replacement of oil by gas. Finally, a numerical simulation sector model of a hypothetical NFR was created and several air-gas injection sequences were analyzed. It was concluded that injection of air (LTO conditions) and propane represents an alternative for heavy oil recovery from NFRs at the field scale, and an optimum production time/soaking time ratio can be obtained for given gas injection sequences (type of gas and injection/soaking durations), temperature, and block sizes.

Download or read book Proceedings of the International Field Exploration and Development Conference 2022 written by Jia'en Lin and published by Springer Nature. This book was released on 2023-08-05 with total page 7600 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book focuses on reservoir surveillance and management, reservoir evaluation and dynamic description, reservoir production stimulation and EOR, ultra-tight reservoir, unconventional oil and gas resources technology, oil and gas well production testing, and geomechanics. This book is a compilation of selected papers from the 12th International Field Exploration and Development Conference (IFEDC 2022). The conference not only provides a platform to exchanges experience, but also promotes the development of scientific research in oil & gas exploration and production. The main audience for the work includes reservoir engineer, geological engineer, enterprise managers, senior engineers as well as professional students.

Download or read book Proceedings of the International Field Exploration and Development Conference 2023 written by Jia’en Lin and published by Springer Nature. This book was released on with total page 1909 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical Simulation in Oil Recovery written by Mary F. Wheeler and published by . This book was released on 1988-01-01 with total page 283 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Investigation of Carbonated Water Injection CWI for Enhanced Oil Recovery at the Pore and Corescale written by Sadigheh Mahdavi and published by . This book was released on 2019 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Oil recovery by CO2 injection has been studied in the laboratory and applied in the field, however, for the most part, CO2 injection lacks acceptable sweep efficiency. Various CO2 injection strategies such as CO2 alternating water and gas (CO2-WAG) and CO2 simultaneous alternating water and gas (CO2-SWAG) have been suggested to alleviate this problem and improve oil recovery. The amount of CO2 required can be a limiting factor especially in offshore applications. Thus, carbonated water injection (CWI) has recently been given considerable attention as it requires less CO2 for the injection and increases the sweep efficiency. This study provides an overview of previous work on the topic and outlines the results of an integrated experimental, theoretical, and simulation investigation of the CWI for enhanced oil recovery (EOR). The effect of carbonated water injection on vertical displacement (gravity effect) at both the pore-scale and core-scale was investigated in this study. The novelty of this research is to investigate the performance of water flooding (WF) and CWI in the presence of gravity using homogeneous and heterogeneous (fractured) porous media. The first phase of this research investigates the pore-scale displacement phenomena which occurs in the presence of CWI in a glass micromodel. Although the effects of many parameters have been studied, an investigation of the effect of gravity displacement and heterogeneous porous media on trapped oil extraction using CWI, is deficient in the current literature. To evaluate the potential use of CWI for vertical displacement and oil extraction, a series of experiments in medium pressure homogeneous and heterogeneous (fractured) micromodels were designed at 2.1 MPa (305 psi) and 21°C (69.8 °F). The oil saturation profile, fluid flow pattern, pore-scale mechanisms, and trapped oil mobilization were analyzed during the experiments. The results of CWI showed an increased vertical sweep efficiency compared to water flooding. The fluid flow pattern in both water flooding and CWI showed that the carbonated water phase has a better sweep efficiency. Secondary CWI resulted in 16.8% additional oil recovery compared to water flooding. After a visual investigation of the impact of CWI on oil recovery and oil distribution in micromodels, core flooding experiments were designed to qualify and compare the effectiveness of water flooding, water alternating CO2 gas (CO2-WAG), and CWI at reservoir conditions considering the solubility of CO2 in seawater and oil. The results of the core flooding experiments were evaluated using a simulation study. The results of core flooding experiments showed that secondary CWI obtained the highest recovery factor of 74.8% compared to 66.5% in CO2-WAG and 64.2% in tertiary CWI processes. The third phase the research was to simulate and predict the experimental results using Computer Modeling Group (CMG version 2014) software. The fluid model was constructed using CMG-WinPropTM to create the compositions and properties of the CO2-oil and CO2-brine mixtures. The fluid model was incorporated into the compositional and unconventional reservoir simulator, CMG-GEMTM, in order to reproduce the CWI and CO2-WAG flooding tests conducted in this study. The simulation results indicated that CWI had a higher oil recovery factor compared to water flooding and CO2-WAG. In summary, this comprehensive study highlights the CWI applicability for vertical oil sweep efficiency and enhanced oil recovery in homogeneous and heterogeneous porous media.

Download or read book Numerical Simulation in Oil Recovery written by Mary E. Wheeler and published by Springer. This book was released on 2012-06-29 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The papers of this book are based on a Symposium on Numerical Simulation in Oil Recovery held at the Institute for Mathematics and its Applications. The major research emphasis is on the modeling of fractures, heterogeneities, viscous fingering, and diffusion-dispersion effects in the flow in porous media. This volume contains seventeen comprehensive papers on the latest developments in this exciting subject. Its diverse presentation brings together the various disciplines of applied mathematics, chemical engineering, physics and hydrology.

Download or read book Numerical simulation of gas injection for upstructure oil drainage written by Richard F. Strickland and published by . This book was released on with total page 148 pages. Available in PDF, EPUB and Kindle. Book excerpt: