Download or read book A Study of the Effect of Gravity on Oil Recovery by Waterflooding written by Alvin Wesley Talash and published by . This book was released on 1965 with total page 86 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Study of the Effect of Viscosity on Oil Recovery by Water Flooding written by Martin Felsenthal and published by . This book was released on 1949 with total page 100 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Study of the Influence of Interstitial Water of Oil Sands on Oil Recovery written by Samuel Soo Hoo and published by . This book was released on 1945 with total page 168 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book The Pore level Investigation of Phenomena Affecting the Recovery of Oil with Gas Assisted Gravity Drainage written by Hossein Khorshidian and published by . This book was released on 2018 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Gas Assisted Gravity Drainage (GAGD) is an effective method of oil recovery that can be implemented injecting gas in the crest of reservoirs and producing oil from lower zones. GAGD is controlled by the interaction between capillary, gravitational and viscous forces, which depend on parameters of the operation, porous medium, and fluids. In this research, the performance of GAGD under various conditions was investigated by visualizing the flow of fluids at the pore-level to understand phenomena affecting the recovery of oil. A new pore network micromodel with an improved capillary continuity was developed that provides a transparent porous medium for studying the interplay between capillary, gravitational and viscous forces. The visualization of fluids' interfaces helped with the characterization of GAGD performance under various conditions. Results of the studies imply that the porous medium heterogeneities caused the gas-front to bypass oil in smaller pores surrounded by larger pores. The bypassed oil could flow in the form of thick films in fine capillaries of porous media upon a subsequent enhancement of the gas-oil capillary pressure due to the effect of gravity on the gas-oil differential density. In the presence of mobile water, a better GAGD performance was obtained under oil-wet conditions as the hydraulic continuity of oil under water-wet conditions can be arrested by the residual water in small pores and fine capillaries of a porous medium. Although the recovery of oil at earlier times after a gas-breakthough was higher under oil-wet conditions, extending the duration of GAGD resulted in a high oil recovery under water-wet conditions upon an effective reduction of the residual water saturation. In post-waterflood GAGD, increasing the production rate resulted in the instability of the gas-front and the reduction of oil recovery at gas-breakthrough because of viscous pressure drops and capillary pressure associated with the flow of oil and water from trailing zones toward leading zones of the gas-front. Experimental results suggest that both oil-wet and water-wet reservoirs are excellent candidates for the implementation of post-waterflood GAGD. However, higher rate of oil drainage with less water production can be expected from early stages of the process in oil-wet reservoirs. Under water-wet conditions, although the production rate of oil is initially low, a very low residual oil saturation can be obtained after an effective reduction of the water saturation.

Download or read book An Experimental and Theoretical Investigation of the Effect of API Gravity Injection Pressure and Oil Composition on Oil Recovery by High Pressure Carbon Dioxide Injection written by Mohammed Baker Alsinbili and published by . This book was released on 1972 with total page 430 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Carbon Dioxide Miscible Flooding written by Gregory Lynn Andrews and published by . This book was released on 1985 with total page 256 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Long Core Study of the Effect of Initial Water Saturation Upon Oil Recovery by Water Flooding written by Peter A. Macqueen and published by . This book was released on 1952 with total page 250 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Visual Investigation of the Effect of Wettability on Oil Recovery by Water Flooding written by Conley Paul Smith and published by . This book was released on 1959 with total page 76 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book A Study of the Effect of the Curtailment of Production on Oil Recovery written by Interstate Oil Compact Commission. Secondary Recovery and Pressure Maintenance Committee and published by . This book was released on 1960 with total page 142 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Waterflooding written by G. Paul Willhite and published by . This book was released on 1986 with total page 358 pages. Available in PDF, EPUB and Kindle. Book excerpt: Waterflooding begins with understanding the basic principles of immiscible displacement, then presents a systematic procedure for designing a waterflood.

Download or read book Conventional and Carbonated Water Flooding in Heavy Oil Systems written by Tayebeh Jamshidi and published by . This book was released on 2018 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Despite the severe viscosity contrast and low displacement efficiency in heavy oil reservoirs, conventional waterflooding is still considered as one of the feasible recovery processes for such reservoirs. On the other hand, conventional waterflooding has been well studied and has been suggested for light oil reservoirs. However, viability of carbonated waterflooding for heavy oil reservoir and impact of operational parameters, reservoir characteristics, and fluid properties on the performance of this technique are yet to be fully understood. In this study, the performances of conventional and carbonated waterflooding in heavy oil reservoirs were analyzed through various micromodel and coreflooding experiments. Prior to the main tests, a series of experiments were performed to investigate the effect of various parameters such as temperature, pressure, and oil API gravity on the fluid interactions in the binary systems of brine-CO2 and oil-CO2. The solubility of carbon dioxide in 20,000 ppm brine solution was measured at various experimental conditions and compared with previous studies. Furthermore, the solubility of CO2 in oil and the swelling factor for two heavy oils (Type-I, oAPI=20.44 and Type-II, oAPI=15.49) were experimentally measured at various conditions. In this regard, CO2 solubility was measured to be 10.13 and 5.72 (gr CO2/100 gr oil) in Type-I crude oil when temperature increased from T=21oC to 45oC at the constant pressure of Pexp=3.44 MPa. When pressure increased from Pexp=1.38 MPa to 3.44 MPa at the constant temperature of T=21oC, solubility of CO2 in Type-II crude oil was increased from 2.37 to 7.84 (gr CO2/100 gr oil). A reduction in oil API gravity had adverse effect on the CO2 solubility. For example, at the temperature of T=21oC and Pressure of Pexp=3.44 MPa, CO2 solubility decreased from about 10.13 (g CO2/100 gr in oil) Type-I to 7.84 (gr CO2/100 gr ii oil) in oil Type-II. Measured values of swelling factor showed that Type-I and Type-II crude oils could swell to the maximum of 1.079 and 1.052 times of their initial volume at the temperature of T=21oC and Pressure of Pexp=3.44 MPa. Effect of key parameters such as injection rate, temperature, oil API gravity and extreme heterogeneity on the performance of both conventional and carbonated waterflooding in heavy oil systems were extensively studied through series of experiments. Results of conventional waterflooding conducted with 1.6 PVs of injected water in the single permeability porous media showed ultimate recovery factors of 48%, 62% and 53.7% for water injection rates of qinj=0.025, 0.05, and 0.075 (cm3/min), respectively. Increasing the temperature from Texp=21oC to 30oC and 45oC improved the ultimate recovery factor of conventional waterflooding in single permeability porous media from 61% to 69.3% and 73%, respectively. These values were achieved at nearly 1.6 PVs of injected water. Analysis of the experimental results at qinj=0.05 (cm3/min) and Texp=21oC revealed an improvement of 2.44% in ultimate recovery factor when oil API gravity increased from oAPI=15.49 to 20.44. Results of this study showed that carbonated waterflooding (CWF) could improve the ultimate recovery factor by 24% compared to WF. Conventional and carbonated waterflooding tests conducted in a sand-packed model revealed that injection at higher carbonation pressure of 3.1 MPa results in 16.5% additional recovery factor in type-I heavy oil compared to heavier oil of type-II. Among API gravity, carbonation pressure, temperature and injection rate, it was found that the key success for CWF is oil API gravity and carbonation pressure.

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 An Investigation of the Effects of Wettability on Oil Recovery After Water Flooding written by Robert Stith Boykin and published by . This book was released on 1954 with total page 78 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Effect of Rate on Oil Recovery by Water Flooding written by J. K. Jordan and published by . This book was released on 1956 with total page 68 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book An Investigation of the Effect of Injection Rate on Oil Recovery by Water Flooding in Stratified Reservoirs written by John Alan Bailey and published by . This book was released on 1959 with total page 80 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book The Effect of Gravity Segregation on Oil Recovery Using Surfactant alternating gas SAG Flooding written by Mohd. Syahid Nor Effendi and published by . This book was released on 2014 with total page 71 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book The Effects of Macroscopic Heterogeneities of Pore Structure and Wettability on Residual Oil Recovery Using the Gravity assisted Inert Gas Injection GAIGI Process written by Rafat Parsaei and published by . This book was released on 2011 with total page 120 pages. Available in PDF, EPUB and Kindle. Book excerpt: To recover oil remaining in petroleum reservoirs after waterflooding, the gravitationally stable mode of gas injection is recognized as a promising tertiary oil recovery process. Understanding the phenomena occurring over the course of the gravity-assisted inert gas injection (GAIGI) process is thus important. Extensive studies on both secondary and tertiary modes of gravity drainage have shown promising results in recovering oil from homogeneous water-wet glass bead packs, sand packs, and sandstone cores, respectively. However, it is not realistic to anticipate similar flow mechanisms and recovery results in all types of reservoirs because the natural hydrocarbon reservoirs are all heterogeneous in terms of their permeability, porosity, and wettability. Such heterogeneities cause irregular displacement patterns, and nonuniform fluid distribution. The impact of heterogeneity of the porous media on the GAIGI process has not been fully addressed in the experimental studies carried out to date; therefore, this thesis aims to fill in the gap of knowledge on this area. The impact of reservoir wettability and pore structure heterogeneities at the macroscopic scale on the recovery efficiency of the GAIGI process was investigated through a systematic experimental study for tertiary recovery of waterflood residual oil. To obtain heterogeneous (in terms of wettability) packings, isolated inclusions of oil-wet consolidated glass beads were embedded in a continuum of unconsolidated water-wet glass beads. Similarly, the heterogeneous porous media exhibiting permeability heterogeneity consisted of large-pore-size isolated regions randomly distributed in a small-pore-size continuum. Upon waterflooding, significantly higher waterflood residual oil saturation was established in both cases of heterogeneous media in comparison to water-wet homogeneous porous media. The amount of waterflood residual oil varied linearly with the volume fraction of heterogeneities in the packings. Experimental results obtained from tertiary gravity drainage experiments demonstrated that the continuity of water-wet portions of the heterogeneous porous media facilitates the residual oil recovery through the film flow mechanism, provided that the oil spreading coefficient is positive. In addition, owing to the high waterflood residual oil content of the heterogeneous media tested, the oil bank formation occurred earlier and grew faster than that in homogeneous media, resulting in a higher oil recovery factor. However, the favorable wettability conditions in both the homogeneous and heterogeneous porous media exhibiting permeability heterogeneity resulted in slightly lower reduced residual oil saturation after the GAIGI process compared to that in the heterogeneous media with wettability heterogeneity under the same condition of withdrawal rate. In addition, the oil recovery factor at gas breakthrough was found to be inversely related to the production rate due to the functionality of gravity and viscous forces over the course of gravity drainage. These two forces were combined into a dimensionless form, defined as the gravity number (Ngv=KDrogg/moVpg). It was discovered that there is a correlation between the oil recovery factor at gas breakthrough and the gravity number for both the heterogeneous and homogeneous media. The correlation of recovery factor at gas breakthrough versus the gravity number in heterogeneous media followed a similar trend as that found for homogeneous water-wet porous media. However, at a given gravity number, the recovery factor in heterogeneous media was greater than that in the homogeneous media. This implies that heterogeneous media will be better target reservoirs for applying the GAIGI process compared to the homogeneous reservoirs.