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 Utilization of Carbonated Water Injection CWI as a Means of Improved Oil Recovery in Light Oil Systems written by Nader Mosavat and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Pore Scale Mechanisms of Carbonated Water Injection in Oil Reservoirs written by Masoud Riazi and published by . This book was released on 2011 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Concerns over the environmental impact of carbon dioxide (CO2) have led to a resurgence of interest in CO2 injection (CO2I) in oil reservoirs, which can enhance oil recovery from these reservoirs and store large quantities of CO2 for a long period of time. Oil displacement and recovery by CO2I has been studied and applied in the field extensively. However, CO2I lacks acceptable sweep efficiency, due to the large viscosity contrast between CO2 and resident reservoir fluids. Various CO2I strategies e.g. alternating (WAG) or simultaneous injection of CO2 and water have been suggested to alleviate this problem. An effective alternative strategy is carbonated (CO2-enriched) water injection. In carbonated water, CO2 exists as a dissolved as opposed to a free phase, hence eliminating the problems of gravity segregation and poor sweep efficiency. In this thesis, the results of an integrated experimental and theoretical investigation of the process of carbonated water injection (CWI) as an injection strategy for enhanced oil recovery (EOR) with the added value of CO2 storage are described. High-pressure micromodel technology was used to physically simulate the process of CWI and visually investigate its EOR potential, at typical reservoir conditions. Using the results of these flow visualisation experiments, the underlying physical processes and the pore-scale mechanisms of fluid-fluid and fluid-solid interactions during CWI were demonstrated to be oil swelling, coalescence of the isolated oil ganglia, wettability alteration, oil viscosity reduction and flow diversion due to flow restriction in some of the pores as a result of oil swelling and the resultant fluid redistribution. A mathematical model was developed that accounts for the pore-scale mechanisms observed during the micromodel experiments. In this study, some of the micromodel experimental observations were interpreted and the impact of some of the pertinent parameters on CWI and CO2I processes was studied. The results predicted by the model were linked to the results obtained using a new relationship developed based on the dimensional analysis technique. To examine and investigate the effect of CWI on wettability, micromodel experiments, designed only to observe possible variation of contact angles and spontaneous imbibition displacement mechanisms due to CW, were performed. Contact angle measurements were also conducted to quantify different tendencies of CW and water to wet solid surfaces, using three different solid plates with different salinity of the aqueous phase, under different pressure and temperature conditions. Two other important parameters affecting the performance of CWI, i.e. CO2 solubility in water and its CO2 diffusion coefficient, were also experimentally studied and estimated. A mathematical model was developed to estimate CO2 diffusion coefficient from the corresponding experimental results. The results of this research show that CWI is an effective and efficient injection strategy that offers great potential for enhanced oil recovery and at the same time a unique solution to the problem of reducing CO2 emission.
Download or read book Gas Injection Methods written by Zhaomin Li and published by Gulf Professional Publishing. This book was released on 2022-09-24 with total page 438 pages. Available in PDF, EPUB and Kindle. Book excerpt: The Enhanced Oil Recovery Series delivers a multivolume approach that addresses the latest research on various types of EOR. The second volume in the series, Gas Injection Methods, helps engineers focus on the latest developments in one of the fastest growing areas. Different techniques are described in addition to the latest technology such as data mining and unconventional reservoirs. Supported field case studies are included to show a bridge between research and practical application, making it useful for both academics and practicing engineers. Structured to start with an introduction on various gas types and different gas injection methods, screening criteria for choosing gas injection method, and environmental issues during gas injection methods, the editors then advance on to more complex content, guiding the engineer into newer topics involving CO2 such as injection in tight oil reservoirs, shale oil reservoirs, carbonated water, data mining, and formation damage. Supported by a full spectrum of contributors, this book gives petroleum engineers and researchers the latest research developments and field applications to drive innovation for the future. Helps readers understand the latest research and practical applications specific to foam flooding and gas injection Provides readers with the latest technology, including nanoparticle-stabilized foam for mobility control and carbon storage in shale oil reservoirs Teaches users about additional methods such as data mining applications and economic and environmental considerations
Download or read book Numerical Simulation of Carbonated Water Injection CWI Process in Live Oil Systems and Its Influences on Enhanced Oil Recovery written by Ali Hassan Mohamed Al Basri Almesmari and published by . This book was released on 2019 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Pore scale Characterization of Wettability and Displacement Mechanisms During Oil Mobilization Due to Waterflood based Oil Recovery Schemes written by Mahdi Khishvand and published by . This book was released on 2018 with total page 217 pages. Available in PDF, EPUB and Kindle. Book excerpt: We present the results of an extensive pore-scale experimental study of trapping of oil in topologically disordered naturally-occurring pore spaces. A unique miniature core-flooding system is built and then integrated with a high-resolution micro-computed tomography (micro-CT) scanner to create a new experimental platform, which enables us to conduct flow experiments on a small rock specimen, nominally 5-mm-diameter, at conditions representative of subsurface reservoirs while the sample is being imaged. We develop robust experimental procedures and state-of-the-art image analysis techniques to characterize in-situ wettability and accurately map the spatial distribution of fluid phases at the pore level during various multiphase flow phenomena. This indeed has the possibility to transform our understanding of these important flow processes and allows us to have a much more effective way of designing enhanced oil recovery schemes deployed in a wide range of geological systems. Below, we list four key applications of this new approach, which are achieved under this study. These include: (1) In-situ characterization of wettability and pore-scale displacement mechanisms; (2) Micro-scale investigation of the effects of flow rate on nonwetting phase trapping; (3) Systematic examination of the impact of brine salinity on residual phase saturation; and (4) Experimental study of the remobilization of trapped oil ganglia associated with CO2 exsolution during carbonated water injection. Initially, we perform several two-phase experiments on Berea sandstone core samples and characterize contact angle hysteresis for various fluid pairs. Afterward, we carry out a three-phase experiment including a secondary gas injection followed by a waterflood and then an oilflood. We generate in-situ oil-water, gas-water, and gas-oil contact angle distributions during each stage of this flow experiment and compare them with the two-phase counterparts to develop new insights into relevant complex displacement mechanisms. The results indicate that, during gas injection, the majority of displacements involving oil and water are oil-to-water events. It is observed that, during the waterflood, both oil-to-gas and gas-to-oil displacement events take place. However, the relative frequency of the former is greater. For the oilflood, gas-water interfaces only slightly hinge in pore elements. Pore-scale fluid occupancy maps and the Bartell-Osterhoff constraint verify the above-mentioned findings. Secondly we conduct a pore-scale experimental study of residual trapping on consolidated water-wet sandstone and carbonate rock samples. We investigate how the changes in wetting phase flow rate impacts pore-scale trapping of the nonwetting phase as well as size and distribution of its disconnected globules. The results show that with increase in imbibition flow rate, the residual oil saturation reduces from 0.46 to 0.20 in Bemtheimer sandstone and from 0.46 to 0.28 in Gambier limestone. The reduction is believed to be caused by alteration of the order in which pore-scale displacements took place during imbibition. We use pore-scale displacement mechanisms, in-situ wettability characteristics, and pore size distribution information to explain the observed capillary desaturation trends. Furthermore, we explore that the volume of individual trapped oil globules decreases at higher brine flow rates. Moreover, it is found that the pore space in the limestone sample is considerably altered through matrix dissolution at extremely high brine flow rates. Imbibition in the altered pore space produces lower residual oil saturation (from 0.28 to 0.22) and significantly different distribution of trapped oil globules. Thirdly, a series of micro- and core-scale flow experiments are carried out on mixed-wet reservoir sandstone core samples at elevated temperature and pressure conditions to examine the impact of injection brine salinity on oil recovery and accentuate governing displacement mechanisms. Individual core samples are cut from a preserved reservoir whole core, saturated to establish initial reservoir fluid saturation conditions, and subsequently waterflooded with low- and high-salinity brines. In addition to the preserved experiments, several samples are cleaned, subjected to a wettability restoration process, and then used for waterflooding experiments. The results indicate approximate waterflood residual oil saturations (S[subscript]orw) of 0.25 and 0.39 for LSWF and HSWF, respectively. These observations highlight the remarkably superior performance of LSWF compared to that of HSWF. LSWF tests show a more prolonged oil recovery response than HSWF. The findings provide direct evidence that LSWF also causes a wettability alteration toward increasing water-wetness – due to limited release of mixed-wet clay particles and multi-component ion exchange, whereas contact angles measured during HSWF remain unchanged. It is observed that the reduction in oil-water contact angles lowers the threshold water pressure needed to displace oil from some medium-sized pore elements and enhances oil recovery during LSWF. Finally, we present the results of a micro-scale three-phase experimental study, using a spreading fluid system, of carbonated water injection and subsequent CO2 exsolution, as a consequence of pressure depletion, that lead to recovery of a significant fraction of trapped oil. Micro-CT visualization of pore occupancy show that the gradual increase in the pressure drop leads to exsolution of CO2, internal gas drive, mobilization of oil ganglia, and a notable reduction in waterflood residual oil saturation. When contacted by CO2, oil globules form thick spreading layers sandwiched between brine (in the corners) and gas (in the center of pores) and are displaced toward the outlet along with moving gas clusters. We observe significant re-connection of trapped oil globules due to oil layer formation during early stages of CWI. The oil layers stay stable until the very late stages of gas exsolution.
Download or read book Enhanced Oil Recovery by Carbon Dioxide and Diethyl Ether as Mutual Solvents written by Ahmed Jamal AlZayer and published by . This book was released on 2017 with total page 180 pages. Available in PDF, EPUB and Kindle. Book excerpt: Increasing the oil recovery factor from existing fields is the key towards meeting future oil demand. The injection of solvents, an established EOR technique, has shown significant improvement in oil recovery over conventional water floods. However, the injection of pure solvent slugs can be quite costly for field operators. To mitigate this problem, recent literature has suggested the use of brines that are saturated with mutual solvents (dissolve in both oil and water) such as Carbon Dioxide (CO2) and Dimethyl Ether (DME). This practice minimizes the amount of used solvent since it is governed by its limited solubility in water. The solubility of CO2 and DME is much higher in oil than in water. Therefore, a mass transfer takes place once CO2 or DME saturated brines come into contact with oil. As these solvents go into the oil phase, they promote oil swelling and reduce the oil viscosity, thereby making it movable and increasing the oil recovery as a result. Although there has been recent lab work performed with this EOR method, most of the work performed so far involved short cores, high injection rates and in some cases limited to sandstone cores. In this thesis, we investigated the effect of using brines that were saturated with CO2 and Diethyl ether (DEE) on oil recovery. The results came out to be mixed and not completely in line with previous literature for CO2 rich brine (Carbonated Water). Injecting carbonated water into sandstone cores did not improve the oil recovery. However, there was an improvement in oil recovery as a result of carbonated water injection in carbonate cores, which also displayed effluent line plugging. For the case of DEE-rich brine, there was a noticeable improvement in oil recovery but it took more pore volumes to have an effect in comparison to DME-rich brine literature results. The experimental work was further supplemented with numerical modeling. The simulator was not able to capture the effects of carbonated water observed in the experiment, due to the absence of rock–fluid interaction in the modeling mechanism. In contrast, the DEE rich brine case was successfully matched with the compositional simulator since it did not involve rock reactions and was strictly based on fluid–fluid interactions
Download or read book Enhanced Oil Recovery written by Marcel Latil and published by Editions TECHNIP. This book was released on 1980 with total page 258 pages. Available in PDF, EPUB and Kindle. Book excerpt: Contents : 1. Factors common to all enhanced recovery methods. 2. Water injection. 3. Gas injection in an oil reservoir (immiscible displacement). 4. Miscible drive. 5. Gas recycling in gas-condensate reservoirs. 6. Thermal recovery methods. 7. Other methods of enhanced recovery. References. Index.
Download or read book Oil recovery by carbon dioxide injection written by Pennzoil Company and published by . This book was released on 1977 with total page 32 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Enhanced Oil Recovery by Carbonated Co2 enriched Water Injection written by Seyyed Mojtaba Seyyedi Nasooh Abad and published by . This book was released on 2017 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Effect of Oil Type on the Performance of Carbonated Water Injection for Enhanced Oil Recovery Under Consistent Operating Condition written by Samia Muhammad AL-Riyamiyah and published by . This book was released on 2016 with total page 122 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Immiscible WAG Injection written by Thuan Dang Quach and published by . This book was released on 2020 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Water Alternating Gas (WAG) injection, commonly used in light to medium crude oil reservoirs, is a well-established technique for enhanced oil recovery combining the effects of two conventional oil recovery processes - water injection and gas injection. Immiscible water alternating gas (IWAG) injection is considered as an appropriate injection type dependent on economical and productive aspects. During the IWAG process, injected gas and oil are always in separate phases due to low-pressure maintenance, and it takes advantages in improving the stability displacement front in the macroscopic sweep as well as enhancing microscopic sweep in narrow pores. In order to check the optimum operational condition in which to apply IWAG injection at the field-scale, this injection process is usually tested as a core-flooding experiment, which is time-consuming and expensive. In this research, a model of core-scale IWAG injection is introduced with validation by Double Displacement Process (DDP) experimental data from previous research. Response Surface Methodology (RSM) with CCD design is used to investigate the impact of five operational parameters on the volume of oil recovery. Particle Swarm Optimization (PSO) is employed to determine the optimum combination of operational parameters to achieve the highest oil recovery factor for each operation scenario. The results indicate that all the main operational parameters, including timing, ratio, flow rate, slug size, and sequence, are significant for the response surface model. The PSO models reach good convergent results, with the volume of oil recovery for each case as 0.613, 0.650, and 0.666 pore volume. The performance of optimum IWAG injection is significantly better than only water-flooding or gas injection, with results approximately 5% higher than water-flooding, similar to double displacement process (DDP), and approximately 20% better than gas injection for the same operational conditions. These optimization tools are recommended for further research of WAG injection, both the experimental and simulation processes.
Download or read book Enhanced Oil Recovery written by M. M. Schumacher and published by William Andrew. This book was released on 1978 with total page 234 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book An Investigation of Parameters Affecting Oil Recovery Efficiency of Carbon Dioxide Flooding in Cross sectional Reservoirs written by Mansour Saleh Almalik and published by . This book was released on 1988 with total page 378 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Enhanced Oil Recovery with Water Injection Sorrento Field Denver Basin Colorado U S A written by Amitabh Varma and published by . This book was released on 2010 with total page 198 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Microbial Enhanced Oil Recovery written by Ryan T. Armstrong and published by . This book was released on 2012 with total page 166 pages. Available in PDF, EPUB and Kindle. Book excerpt: Current oil production technologies recover only about one-third to one-half of the oil originally present in an oil reservoir. Given current oil prices, even a modest increase in oil recovery efficiency is fiscally attractive. One novel approach to increase oil recovery efficiency is a process called microbial enhanced oil recovery (MEOR), where microorganisms are either used as a clogging agent to redirect flow or to produce biosurfactant that reduces interfacial tension. This dissertation aims to understand the MEOR pore-scale mechanisms relevant to oil recovery by taking a two-fold approach where transparent 2-dimensional micromodel experiments imaged with stereo microscopy and 3-dimensional column experiments imaged with x-ray computed microtomography (CMT) are utilized. Micromodel experiments allow for direct visualization of the biological phase (i.e. biofilm), however, only 2-dimensional information is provided. Conversely, CMT experiments provide 3-dimensional pore-scale information, but lack the ability to image the biological phase. With this two-fold approach, it is possible to distinguish multiple fluid interfaces, quantify fluid phase saturations, measure oil blob size distributions, and visualize the biological phase. Furthermore, a method to measure interfacial curvature from 3-dimensional images is developed, providing researchers a new perspective from which to study multiphase flow experiments. Overall, the presented research utilizes pore-scale imaging techniques to study the interfacial interactions occurring during MEOR in an effort to better explain the physics, and thus, increase the efficacy of MEOR.
Download or read book Enhanced Oil Recovery by Low Salinity Water Injection in Carbonate Reservoirs written by Mohamed Ibrahim AlHammadi and published by . This book was released on 2019 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:
