Download or read book Investigation of Phase Behavior and Reservoir Fluid Properties in Support of Enhanced Oil Recovery of Alaska North Slope ANS Viscous Oils written by Kaustubh D. Alurkar and published by . This book was released on 2007 with total page 224 pages. Available in PDF, EPUB and Kindle. Book excerpt: "Declining light oil production on Alaska North Slope (ANS) has attracted oil producers to develop viscous oil resources of ANS that range between 20 to 25 billion barrels. These oils are viscous, flow sluggishly in the formations, and are difficult to transport through unconsolidated formations and are hard to produce by conventional methods. Viscous oil recovery entails neatly designed enhanced oil recovery processes and the success of these processes is critically dependent on accurate knowledge of phase behavior and fluid properties of these oils under variety of pressure and temperature conditions. An experimental study was conducted to quantify the phase behavior and physical properties of viscous oils from ANS. The oil samples were compositionally characterized by simulated distillation technique, constant composition expansion and differential liberation tests were conducted on these samples. Experimentally studied phase behavior and reservoir fluid properties were modeled by using the Peng-Robinson Equation-of-State (EOS). The Peng-Robinson EOS was tuned with experimental data to predict the phase behavior, accurately. Widely used corresponding state viscosity model predictions deteriorate when applied to heavy oil systems due to use of ultra-light methane as a reference compound. Therefore, a semi empirical approach (Lindeloff model) was adopted for modeling the viscosity behavior. Viscosity behavior of degassed ANS viscous oils was correlated to their temperature and molecular weight. Integration of this correlation into the Lindeloff model resulted in accurate viscosity predictions for viscous oils under reservoir conditions"--Leaf iii.

Download or read book Phase Behavior Solid Organic Precipitation and Mobility Characterization Studies in Support of Enhanced Heavy Oil Recovery on the Alaska North Slope written by and published by . This book was released on 2008 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The medium-heavy oil (viscous oil) resources in the Alaska North Slope are estimated at 20 to 25 billion barrels. These oils are viscous, flow sluggishly in the formations, and are difficult to recover. Recovery of this viscous oil requires carefully designed enhanced oil recovery processes. Success of these recovery processes is critically dependent on accurate knowledge of the phase behavior and fluid properties, especially viscosity, of these oils under variety of pressure and temperature conditions. This project focused on predicting phase behavior and viscosity of viscous oils using equations of state and semi-empirical correlations. An experimental study was conducted to quantify the phase behavior and physical properties of viscous oils from the Alaska North Slope oil field. The oil samples were compositionally characterized by the simulated distillation technique. Constant composition expansion and differential liberation tests were conducted on viscous oil samples. Experiment results for phase behavior and reservoir fluid properties were used to tune the Peng-Robinson equation of state and predict the phase behavior accurately. A comprehensive literature search was carried out to compile available compositional viscosity models and their modifications, for application to heavy or viscous oils. With the help of meticulously amassed new medium-heavy oil viscosity data from experiments, a comparative study was conducted to evaluate the potential of various models. The widely used corresponding state viscosity model predictions deteriorate when applied to heavy oil systems. Hence, a semi-empirical approach (the Lindeloff model) was adopted for modeling the viscosity behavior. Based on the analysis, appropriate adjustments have been suggested: the major one is the division of the pressure-viscosity profile into three distinct regions. New modifications have improved the overall fit, including the saturated viscosities at low pressures. However, with the limited amount of geographically diverse data, it is not possible to develop a comprehensive predictive model. Based on the comprehensive phase behavior analysis of Alaska North Slope crude oil, a reservoir simulation study was carried out to evaluate the performance of a gas injection enhanced oil recovery technique for the West Sak reservoir. It was found that a definite increase in viscous oil production can be obtained by selecting the proper injectant gas and by optimizing reservoir operating parameters. A comparative analysis is provided, which helps in the decision-making process.

Download or read book Analysis of Phase Behavior and Reservoir Fluid Properties in Support of Wax Deposition Study of Alaska North Slope ANS Crude Oils written by Vijay Balwant Kulkarni and published by . This book was released on 2008 with total page 176 pages. Available in PDF, EPUB and Kindle. Book excerpt: "An experimental study was conducted to quantify the phase behavior and physical properties of Alaskan North Slope stock tank and live crude oils. Measurement of molecular weight, gas-oil ratio, and constant composition expansion and differential liberation tests were conducted on these samples. Phase behavior and reservoir fluid properties of the live oil samples were modeled using the Peng-Robinson Equation-of-State (EOS). The Peng-Robinson EOS was tuned with experimental data to predict the phase behavior accurately. The results of the modeling yielded a satisfactory match with measured saturation pressure and solution gas-oil ratio. This tuned EOS can be incorporated into the compositional reservoir simulator for field scale simulations of Alaska North Slope. The phase envelope obtained from this tuned PR-EOS when combined with wax phase envelope can help to design the production PT pathway. The measured gas-oil ratio of the bottomhole samples was compared to the crude oil composition and showed that higher the composition of C5-C10 in crude oil, greater is the gas-oil ratio"--Leaf iii.

Download or read book Experimental Investigation of Nonthermal Enhanced Oil Recovery Techniques for Improving Oil Recovery on Alaska North Slope written by and published by . This book was released on 2022 with total page 382 pages. Available in PDF, EPUB and Kindle. Book excerpt: Exploitation of viscous and heavy oils on Alaska North Slope (ANS) requires nonthermal enhanced oil recovery (EOR) techniques. Currently, three nonthermal EOR methods, including solvent injection, low salinity water (LSW) flooding, and low salinity polymer (LSP) injection, have been proved to be useful on ANS. ANS viscous and heavy oils can be developed effectively by combining those three nonthermal EOR techniques. In this dissertation, lab experiments have been conducted to investigate the potential of the proposed hybrid nonthermal EOR techniques, including HSW (high salinity water)-LSW-softened LSW flooding, HSW-LSW-LSP flooding, CO2-enriched LHS (light hydrocarbon solvent)-alternating-LSW flooding, LHS-alternating-LSW flooding, CO2-enriched LHS (light hydrocarbon solvent)-alternating-LSP flooding, and LHS-alternating-LSP flooding, to improve ANS viscous oil recovery. Besides, the effect of essential clay minerals, including sodium-based montmorillonite (Na-Mt), calcium-based montmorillonite (Ca-Mt), illite, and kaolinite, on LSW flooding has been examined. In addition, the CO2 influence on solvent-alternating-LSP flooding in enhancing ANS viscous oil recovery has been investigated. Furthermore, the blockage issue during CO2-enriched LHS-alternating-LSP flooding has been investigated, and its solution has been proposed and analyzed. The EOR potential of the proposed hybrid EOR techniques has been evaluated by conducting coreflooding experiments. Additionally, relative permeability, swelling property, zeta potential, interfacial tension (IFT), and pressure-volume-temperature (PVT) tests have been conducted to reveal the EOR mechanisms of the proposed hybrid EOR techniques. Moreover, water ion analysis of DI-water/natural-sand and DI-water/natural-sand/CO2 systems has been carried out to reveal the complex reaction between CO2, sand, and LSP solution. It was found that, compared to conventional waterflooding, all the proposed hybrid EOR techniques could result in better oil recovery potential. It was noticed that the presence of CO2 in LHS could be more beneficial to the solvent-alternating-LSW/LSP flooding processes during the 1st cycle due to the greater effectiveness of oil viscosity reduction. In particular, severe blockage issue occurred when conducting CO2-enriched LHS-alternating-LSP flooding using sand pack due to the polymer precipitation. Additionally, the calculated water relative permeabilities are much lower than the typical values, implying more complex interactions between the reservoir rock, heavy oil, and injected water. Moreover, comparing to HSW, LSW could further swell Na-Mt significantly, which may benefit LSW flooding by improving sweep efficiency since in-situ swelling of Na-Mt has the potential to block the higher permeable water-flooded zone and divert the injected brine to lower permeable and unswept area. Comparing to Na-Mt, LSW couldn’t swell Ca-Mt and illite further, whereas kaolinite was incapable of swelling in both HSW and LSW. Furthermore, about 60 mole% of solvent could be dissolved into the ANS viscous oil at target reservoir condition, resulting in oil swelling and viscosity reduction effects, which provided better microscopic displacement efficiency. Although the presence of CO2 in LHS had a negative impact on the oil swelling effect, the influence on the oil viscosity reduction was positive. In addition, reducing the salinity of water could generate more negative zeta potential values on the surface of clay minerals and sand, making it more water wet. Besides, IFT of oil/LSW system is higher than that of oil/HSW system, indicating that IFT reduction is not an EOR mechanism of LSW flooding in our proposed hybrid EOR techniques. Additionally, after introducing CO2 to the DIwater/natural-sand system, the concentration of multivalent cations was increased, which may be responsible for the polymer precipitation. The blockage issue could be solved by injecting LSW as a spacer between CO2-enriched LHS injection and LSP injection.

Download or read book Petroleum Fluid Phase Behavior written by Raj Deo Tewari and published by CRC Press. This book was released on 2018-12-14 with total page 381 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book deals with complex fluid characterization of oil and gas reservoirs, emphasizing the importance of PVT parameters for practical application in reservoir simulation and management. It covers modeling of PVT parameters, QA/QC of PVT data from lab studies, EOS modeling, PVT simulation and compositional grading and variation. It describes generation of data for reservoir engineering calculations in view of limited and unreliable data and techniques like downhole fluid analysis and photophysics of reservoir fluids. It discusses behavior of unconventional reservoirs, particularly for difficult resources like shale gas, shale oil, coalbed methane, reservoirs, heavy and extra heavy oils.

Download or read book Chemical and Microbial Characterization of North Slope Viscous Oils to Assess Viscosity Reduction and Enhanced Recovery written by and published by . This book was released on 2008 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: A large proportion of Alaska North Slope (ANS) oil exists in the form of viscous deposits, which cannot be produced entirely using conventional methods. Microbially enhanced oil recovery (MEOR) is a promising approach for improving oil recovery for viscous deposits. MEOR can be achieved using either ex situ approaches such as flooding with microbial biosurfactants or injection of exogenous surfactant-producing microbes into the reservoir, or by in situ approaches such as biostimulation of indigenous surfactant-producing microbes in the oil. Experimental work was performed to analyze the potential application of MEOR to the ANS oil fields through both ex situ and in situ approaches. A microbial formulation containing a known biosurfactant-producing strain of Bacillus licheniformis was developed in order to simulate MEOR. Coreflooding experiments were performed to simulate MEOR and quantify the incremental oil recovery. Properties like viscosity, density, and chemical composition of oil were monitored to propose a mechanism for oil recovery. The microbial formulation significantly increased incremental oil recovery, and molecular biological analyses indicated that the strain survived during the shut-in period. The indigenous microflora of ANS heavy oils was investigated to characterize the microbial communities and test for surfactant producers that are potentially useful for biostimulation. Bacteria that reduce the surface tension of aqueous media were isolated from one of the five ANS oils (Milne Point) and from rock oiled by the Exxon Valdez oil spill (EVOS), and may prove valuable for ex situ MEOR strategies. The total bacterial community composition of the six different oils was evaluated using molecular genetic tools, which revealed that each oil tested possessed a unique fingerprint indicating a diverse bacterial community and varied assemblages. Collectively we have demonstrated that there is potential for in situ and ex situ MEOR of ANS oils. Future work should focus on lab and field-scale testing of ex situ MEOR using Bacillus licheniformis as well as the biosurfactant-producing strains we have newly isolated from the Milne Point reservoir and the EVOS environment.

Download or read book Experimental Investigation of Low Salinity Enhanced Oil Recovery Potential and Wettability Characterization of Alaska North Slope Cores written by Shivkumar B. Patil and published by . This book was released on 2007 with total page 176 pages. Available in PDF, EPUB and Kindle. Book excerpt: "Rock wettability and the chemical properties of the injection water influence fluid distribution and multiphase fluid flow behavior in petroleum reservoirs and hence it consequently affects the final residual oil saturation. Many researchers have proven that oil recovery is increased by decreasing the salinity of water used for waterflooding process. Three sets of experiments were conducted on representative Alaska North Slope (ANS) core samples to experimentally ascertain the influence of injected brine/fluid composition on wettability and hence on oil recovery in secondary oil recovery mode. All the sets of experiments examined the effect of brine salinity variation on wettability and residual oil saturation of representative core samples. The core samples used in the first and third set were new (clean) while in the second set core samples were oil aged. For first and second sets laboratory reconstituted 22,000 TDS, 11,000 TDS and 5,500 IDS (total dissolved solids) brines were used while for the third set ANS lake water was used. Oil aging of core decreased the water wetting state of cores slightly. This observation could be attributed to adsorption of polar compounds of crude oil. The general trend observed in all the coreflood experiment was reduction in Sor (up to 20%) and slight increase in the Amott-Harvey Wettability Index with decrease in salinity of the injected brine at reservoir temperature"--Leaf iii.

Download or read book Determination of Minimum Miscibility Pressure Using Vanishing Interfacial Tension in Support of Alaska North Slope Heavy Oil Development written by Vinit Santosh Tathed and published by . This book was released on 2008 with total page 194 pages. Available in PDF, EPUB and Kindle. Book excerpt: "Developing Alaskan heavy oils resources has become necessary as, the production from light oil fields in Alaska's North Slope (ANS) is on the decline. Due to the extremely viscous nature of these heavy oils, they are hard to produce by natural pressure. Miscible gas injection Enhanced Oil Recovery (EOR) can be one of the methods for production of these heavy oils. Minimum miscibility pressure (MMP) is an important optimization parameter for EOR processes involving CO2 or hydrocarbon gas injection. The MMP for a gas-oil system is directly related to the interfacial tension between the injected gas and the reservoir crude oil. In this study, a new technique called Vanishing Interfacial Tension (VIT) was used to measure MMP at reservoir conditions. Experiments were conducted using various gas-oil systems to determine the MMP. The experimental results were modeled using the Peng-Robinson Equation-of-State (EOS) with a commercial simulator (CMG). The Peng-Robinson EOS was tuned with experimental data to predict the MMP accurately. This study has demonstrated the accuracy of the VIT technique in predicting MMP by pendant drop method experiments and simulations using CMG software."--Leaf iii.

Download or read book Experimental Investigation of Low Salinity Water Flooding to Improve Viscous Oil Recovery from the Schrader Bluff Reservoir on Alaska North Slope written by 程耀泽 and published by . This book was released on 2018 with total page 188 pages. Available in PDF, EPUB and Kindle. Book excerpt: Alaska's North Slope (ANS) contains vast resources of viscous oil that have not been developed efficiently using conventional water flooding. Although thermal methods are most commonly applied to recover viscous oil, they are impractical on ANS because of the concern of thawing the permafrost, which could cause disastrous environmental damage. Recently, low salinity water flooding (LSWF) has been considered to enhance oil recovery by reducing residual oil saturation in the Schrader Bluff viscous oil reservoir. In this study, lab experiments have been conducted to investigate the potential of LSWF to improve heavy oil recovery from the Schrader Bluff sand. Fresh-state core plugs cut from preserved core samples with original oil saturations have been flooded sequentially with high salinity water, low salinity water, and softened low salinity water. The cumulative oil production and pressure drops have been recorded, and the oil recovery factors and residual oil saturation after each flooding have been determined based on material balance. In addition, restored-state core plugs saturated with viscous oil have been employed to conduct unsteady-state displacement experiments to measure the oil-water relative permeabilities using high salinity water and low salinity water, respectively. The emulsification of provided viscous oil and low salinity water has also been investigated. Furthermore, the contact angles between the crude oil and reservoir rock have been measured. It has been found that the core plugs are very unconsolidated, with porosity and absolute permeability in the range of 33% to 36% and 155 mD to 330 mD, respectively. A produced crude oil sample having a viscosity of 63 cP at ambient conditions was used in the experiments. The total dissolved solids (TDS) of the high salinity water and the low salinity water are 28,000 mg/L and 2,940 mg/L, respectively. Softening had little effect on the TDS of the low salinity water, but the concentration of Ca2+ was reduced significantly. The residual oil saturations were reduced gradually by applying LSWF and softened LSWF successively after high salinity water flooding. On average, LSWF can improve viscous oil recovery by 6.3% OOIP over high salinity water flooding, while the softened LSWF further enhances the oil recovery by 1.3% OOIP. The pressure drops observed in the LSWF and softened LSWF demonstrate more fluctuation than that in the high salinity water flooding, which indicates potential clay migration in LSWF and softened LSWF. Furthermore, it was found that, regardless of the salinities, the calculated water relative permeabilities are much lower than the typical values in conventional systems, implying more complex reactions between the reservoir rock, viscous oil, and injected water. Mixing the provided viscous oil and low salinity water generates stable water-in-oil (W/O) emulsions. The viscosities of the W/O emulsions made from water-oil ratios of 20:80 and 50:50 are higher than that of the provided viscous oil. Moreover, the contact angle between the crude oil and reservoir rock in the presence of low salinity water is larger than that in the presence of high salinity water, which may result from the wettability change of the reservoir rock by contact with the low salinity water.

Download or read book Fluid Characterization and Phase Behavior Studies of Oil from the Frozen Reservoir of Umiat Oil Field Alaska written by Chinmay Shukla and published by . This book was released on 2011 with total page 206 pages. Available in PDF, EPUB and Kindle. Book excerpt: Umiat oil field is the largest oil accumulation in National Petroleum Reserve (NPRA) No. 4 of Alaska. Shallow reservoir depths, low reservoir pressures, and low temperatures with most of the oil-producing zone in a continuous layer of permafrost are unique characteristics that make Umiat reservoir unconventional and difficult to produce. However, unavailability of fluid characterization and phase behavior data needed for reservoir simulation studies pose challenges in developing an effective production strategy. Given the conspicuous lack of complete fluid data on Umiat oils and the unavailability of live oil samples from Umiat, an experimental study was undertaken to characterize and quantify phase behavior of an available small volume of dead Umiat oil. The oil composition characterized experimentally was found to be severely weatherized and not representative of original Umiat oil. Comparison of components in the dead oil sample origina one characterized by Pedersen method enabled determination of the mass of each component that would be need to be added to the weathered sample in order to compensate for the evaporated light ends. The re-created sample was subsequently used for constant composition expansion (CCE) laboratory PVT test. The bubble point pressure at reservoir temperatures, and densities and viscosities of single-phase reservoir fluid at various pressures were measured. The phase behavior of the pseudo live oil was also simulated using Peng-Robinson equations of state (PR-EOS). The EOS model was tuned with measured experimental data to simulate differential liberation tests in order to obtain the PVT data needed for reservoir simulation studies.

Download or read book Miscible Enhanced Oil Recovery Studies for Schrader Bluff Heavy Oil Reservoir North Slope of Alaska written by Maruti S. Inaganti and published by . This book was released on 1994 with total page 278 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Phase Behavior of Petroleum Reservoir Fluids written by Karen Schou Pedersen and published by CRC Press. This book was released on 2014-12-18 with total page 463 pages. Available in PDF, EPUB and Kindle. Book excerpt: Developed in conjunction with several oil companies using experimental data for real reservoir fluids, Phase Behavior of Petroleum Reservoir Fluids introduces industry standard methods for modeling the phase behavior of petroleum reservoir fluids at different stages in the process. Keeping mathematics to a minimum, this book discusses sampling, cha

Download or read book A Study of Waterflood Sweep Efficiency in a Complex Viscous Oil Reservoir written by Marc Daniel Jensen and published by . This book was released on 2014 with total page 134 pages. Available in PDF, EPUB and Kindle. Book excerpt: West Sak is a multi-billion barrel viscous oil accumulation on the North Slope of Alaska. The unique geologic complexities and fluid properties of the West Sak reservoir make understanding ultimate sweep efficiency under waterflood a challenge. This project uses uncertainty modeling to evaluate the ultimate sweep efficiency in the West Sak reservoir and honors a rich dataset gathered from 30 years of development history. A sector model encompassing the area of the West Sak commercial pilot was developed and a sensitivity analysis conducted to determine the most important parameters affecting sweep efficiency. As part of this process unique constraints were incorporated into the model including measured saturations at the end of history, and observed completion performance. The workflow for this project was documented and can be adapted for use in larger scale models. The workflow includes the development of static cell properties which accurately represent field behavior, a preliminary history match using conventional methods and a sensitivity analysis employing a multi-run visualization tool to effectively navigate and process large amounts of data. The main contributions of this work include the identification of key parameters affecting sweep efficiency in the West Sak oil field, a documented workflow, and increased insight into observed production behavior.

Download or read book DEVELOPMENT OF SHALLOW VISCOUS OIL RESERVES IN NORTH SLOPE written by and published by . This book was released on 2004 with total page 122 pages. Available in PDF, EPUB and Kindle. Book excerpt: North Slope of Alaska has huge oil deposits in heavy oil reservoirs such as Ugnu, West Sak and Shrader Bluff etc. The viscosity of the last two reservoir oils vary from (almost equal to)30 cp to (almost equal to)3000 cp and the amount in the range of 10-20 billion barrels. High oil viscosity and low formation strength impose problems to high recovery and well productivity. Water-alternate-gas injection processes can be effective for the lower viscosity end of these deposits in West Sak and Shrader Bluff. Several gas streams are available in the North Slope containing NGL and CO2 (a greenhouse gas). The goal of this research is to develop tools to find optimum solvent, injection schedule and well-architecture for a WAG process in North Slope shallow sand viscous oil reservoirs. Coreflood, quarter 5-spot study, compositional simulation, wettability, relative permeability study and streamline-based simulation were conducted in this project. 1D compositional simulation results agree reasonably well with those of the slim tube experiments. Injection of CO2-NGL is preferable over that of PBG-NGL. MME is sensitive to pressure (in the range of 1300-1800 psi) for the injection of PBG-NGL, but not for CO2-NGL. Three hydrocarbon phases form in this pressure range. As the mean thickness of the adsorbed organic layer on minerals increases, the oil-water contact angle increases. The adsorbed organic films left behind after extraction of oil by common aromatic solvents used in core studies, such as toluene and decalin, are thinner than those left behind by non-aromatic solvents, such as cyclohexane. The force of adhesion for minerals aged with just the asphaltene fraction is similar to that of the whole oil implying that asphaltenes are responsible for the mixed-wettability in this reservoir. A new relative permeability model for a four-phase, mixed-wet system has been proposed. A streamline module is developed which can be incorporated in an existing finite-difference based compositional simulator to model water flood, gas flood and WAG flood. Horizontal wells increase well deliverability over vertical wells, but sweep efficiency can decrease. The well performance depends on the well length, position, heterogeneity, and viscosity ratio. The productivity increase due to electromagnetic heating is a function of power intensity, flow rate, and frequency etc. The productivity of a well can be doubled by electromagnetic heating. A high-pressure quarter 5-spot model has been constructed to evaluate the sweep efficiency of miscible WAG floods. WAG displacement reduces bypassing compared to gas floods and improves oil recovery in cores. As the WAG ratio decreased and slug size increased, oil recovery increased. Oil was recovered faster with increased slug size and decreased WAG ratio in the simulations for field cases studied.

Download or read book Equation of State Model Development and Compositional Simulation of Enhanced Oil Recovery Using Gas Injection for the West Sak Heavy Oil written by Ganesh G. Morye and published by . This book was released on 2007 with total page 172 pages. Available in PDF, EPUB and Kindle. Book excerpt: "West Sak oil field, with its very huge reserves of heavy oil, has the potential of supplementing the declining light oil production on the Alaska North Slope. Due to the heavy nature of oil, its phase behavior is very complex. A proper understanding of the phase behavioral changes of the West Sak oil is crucial to design any enhanced oil recovery scheme. Such Enhanced Oil Recovery (EOR) techniques are essential in the absence of natural drive mechanisms in these reservoirs. For the proper selection of any EOR technique, reservoir simulation studies should prove its viability. Accordingly, a complete phase behavior analysis of the West Sak crude oil was carried out. All the available experimental data was scrutinized and a model equation of state was developed that should describe the phase behavior of West Sak oil. After having done that, reservoir simulation was carried out to study the implications of employing gas injection as an EOR technique for the West Sak reservoir. It was found that a definite increase in heavy oil production can be obtained with proper selection of injectant gas and optimized reservoir operating parameters. A comparative analysis is provided which should help in making such a decision"--Leaf iii.

Download or read book Petroleum Abstracts written by and published by . This book was released on 1986 with total page 1674 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Enhanced Oil Recovery Field Case Studies written by James J. Sheng and published by Elsevier Inc. Chapters. This book was released on 2013-04-10 with total page 43 pages. Available in PDF, EPUB and Kindle. Book excerpt: In this chapter, the fundamentals of surfactant flooding are covered, which include microemulsion properties, phase behavior, interfacial tension, capillary desaturation, surfactant adsorption and retention, and relative permeabilities. The surfactant–polymer interactions are discussed. The mechanisms and screening criteria are briefly discussed. The field cases presented include low-tension waterflooding (Loma Novia, Wichita County Regular field), sequential micellar/polymer flooding (El Dorado, Sloss), micellar/polymer flooding (Torchlight and Delaware-Childers), and Minas SP project preparation and SP flooding (Gudong).