Download or read book Reservoir Characterization of Bridgeport and Cypress Sandstones in Lawrence Field Illinois to Improve Petroleum Recovery by Alkaline Surfactant Polymer Flood written by and published by . This book was released on 2012 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Within the Illinois Basin, most of the oilfields are mature and have been extensively waterflooded with water cuts that range up to 99% in many of the larger fields. In order to maximize production of significant remaining mobile oil from these fields, new recovery techniques need to be researched and applied. The purpose of this project was to conduct reservoir characterization studies supporting Alkaline-Surfactant-Polymer Floods in two distinct sandstone reservoirs in Lawrence Field, Lawrence County, Illinois. A project using alkaline-surfactantpolymer (ASP) has been established in the century old Lawrence Field in southeastern Illinois where original oil in place (OOIP) is estimated at over a billion barrels and 400 million barrels have been recovered leaving more than 600 million barrels as an EOR target. Radial core flood analysis using core from the field demonstrated recoveries greater than 20% of OOIP. While the lab results are likely optimistic to actual field performance, the ASP tests indicate that substantial reserves could be recovered even if the field results are 5 to 10% of OOIP. Reservoir characterization is a key factor in the success of any EOR application. Reservoirs within the Illinois Basin are frequently characterized as being highly compartmentalized resulting in multiple flow unit configurations. The research conducted on Lawrence Field focused on characteristics that define reservoir compartmentalization in order to delineate preferred target areas so that the chemical flood can be designed and implemented for the greatest recovery potential. Along with traditional facies mapping, core analyses and petrographic analyses, conceptual geological models were constructed and used to develop 3D geocellular models, a valuable tool for visualizing reservoir architecture and also a prerequisite for reservoir simulation modeling. Cores were described and potential permeability barriers were correlated using geophysical logs. Petrographic analyses were used to better understand porosity and permeability trends in the region and to characterize barriers and define flow units. Diagenetic alterations that impact porosity and permeability include development of quartz overgrowths, sutured quartz grains, dissolution of feldspar grains, formation of clay mineral coatings on grains, and calcite cementation. Many of these alterations are controlled by facies. Mapping efforts identified distinct flow units in the northern part of the field showing that the Pennsylvanian Bridgeport consists of a series of thick incised channel fill sequences. The sandstones are about 75-150 feet thick and typically consist of medium grained and poorly sorted fluvial to distributary channel fill deposits at the base. The sandstones become indistinctly bedded distributary channel deposits in the main part of the reservoir before fining upwards and becoming more tidally influenced near their top. These channel deposits have core permeabilities ranging from 20 md to well over 1000 md. The tidally influenced deposits are more compartmentalized compared to the thicker and more continuous basal fluvial deposits. Fine grained sandstones that are laterally equivalent to the thicker channel type deposits have permeabilities rarely reaching above 250 md. Most of the unrecovered oil in Lawrence Field is contained in Pennsylvanian Age Bridgeport sandstones and Mississippian Age Cypress sandstones. These reservoirs are highly complex and compartmentalized. Detailed reservoir characterization including the development of 3-D geologic and geocellular models of target areas in the field were completed to identify areas with the best potential to recover remaining reserves including unswept and by-passed oil. This project consisted of tasks designed to compile, interpret, and analyze the data required to conduct reservoir characterization for the Bridgeport and Cypress sandstones in pilot areas in anticipation of expanded implementation of ASP flooding ...
Download or read book Chemical Nanofluids in Enhanced Oil Recovery written by Rahul Saha and published by CRC Press. This book was released on 2021-09-14 with total page 170 pages. Available in PDF, EPUB and Kindle. Book excerpt: Sustainable world economy requires a steady supply of crude oil without any production constraints. Thus, the ever-increasing energy demand of the entire world can be mostly met through the enhanced production from crude oil from existing reservoirs. With the fact that newer reservoirs with large quantities of crude oil could not be explored at a faster pace, it will be inevitable to produce the crude oil from matured reservoirs at an affordable cost. Among alternate technologies, the chemical enhanced oil recovery (EOR) technique has promising potential to recover residual oil from matured reservoirs being subjected to primary and secondary water flooding operations. Due to pertinent complex phenomena that often have a combinatorial role and influence, the implementation of chemical EOR schemes such as alkali/surfactant/polymer flooding and their combinations necessitates upon a fundamental understanding of the potential mechanisms and their influences upon one another and desired response variables. Addressing these issues, the book attempts to provide useful screening criteria, guidelines, and rules of thumb for the identification of process parametric sets (including reservoir characteristics) and response characteristics (such as IFT, adsorption etc.,) that favor alternate chemical EOR systems. Finally, the book highlights the relevance of nanofluid/nanoparticle for conventional and unconventional reservoirs and serves as a needful resource to understand the emerging oil recovery technology. Overall, the volume will be of greater relevance for practicing engineers and consultants that wish to accelerate on field applications of chemical and nano-fluid EOR systems. Further, to those budding engineers that wish to improvise upon their technical know-how, the book will serve as a much-needed repository.
Download or read book Chemical Methods written by Abdolhossein Hemmati-Sarapardeh and published by Gulf Professional Publishing. This book was released on 2021-11-30 with total page 510 pages. Available in PDF, EPUB and Kindle. Book excerpt: Chemical Methods, a new release in the Enhanced Oil Recovery series, helps engineers focus on the latest developments in one fast-growing area. Different techniques are described in addition to the latest technologies in data mining and hybrid processes. Beginning with an introduction to chemical concepts and polymer flooding, the book then focuses on more complex content, guiding readers into newer topics involving smart water injection and ionic liquids for EOR. Supported field case studies illustrate a bridge between research and practical application, thus making the book useful for academics and practicing engineers. This series delivers a multi-volume approach that addresses the latest research on various types of EOR. Supported by a full spectrum of contributors, this book gives petroleum engineers and researchers the latest developments and field applications to drive innovation for the future of energy. Presents the latest research and practical applications specific to chemical enhanced oil recovery methods Helps users understand new research on available technology, including chemical flooding specific to unconventional reservoirs and hybrid chemical options Includes additional methods, such as data mining applications and economic and environmental considerations
Download or read book Microbial Enhanced Oil Recovery written by Lalit Pandey and published by Springer Nature. This book was released on 2021-10-21 with total page 272 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book presents the fundamentals of the reservoir and interfacial engineering. The book systematically starts with the basics of primary, secondary and tertiary (enhanced) oil recovery and emphasizes on the theory of microbial-enhanced oil recovery (MEOR) and its potential toward recovery of oil in place. Different approaches of MEOR such as in-situ, ex-situ, and integration of chemical- and microbial-enhanced oil recovery (EOR) are discussed in detail. This book highlights the link between the effectiveness of MEOR and the local reservoir conditions, crude oil characteristics, and indigenous microbial community. The latest implementations of MEOR across the globe are highlighted as case studies to outline the potential as well as the scope of MEOR. Given the topics covered, this book will be useful for professionals and researchers working in the areas of petroleum science and engineering, chemical engineering, biotechnology, bioengineering, and other related fields.
Download or read book Fluvial Tidal Sedimentology written by and published by Elsevier. This book was released on 2015-11-26 with total page 719 pages. Available in PDF, EPUB and Kindle. Book excerpt: Fluvial-Tidal Sedimentology provides information on the ‘Tidal-Fluvial Transition', the transition zone between river and tidal environments, and includes contributions that address some of the most fundamental research questions, including how the morphology of the tidal-fluvial transition zone evolves over short (days) and long (decadal) time periods and for different tidal and fluvial regimes, the structure of the river flow as it varies in its magnitude over tidal currents and how this changes at the mixing interface between fresh and saline water and at the turbidity maximum, the role of suspended sediment in controlling bathymetric change and bar growth and the role of fine-grained sediment (muds and flocs), whether it is possible to differentiate between ‘fluvial’ and ‘tidally’ influenced bedforms as preserved in bars and within the adjacent floodplain and what are the diagnostic sedimentary facies of tidal-fluvial deposits and how are these different from ‘pure’ fluvial and tidal deposits, amongst other topics. The book presents the latest research on the processes and deposits of the tidal-fluvial transition, documenting recent major field programs that have quantified the flow, sediment transport, and bed morphology in tidal-fluvial zones. It uses description of contemporary environments and ancient outcrop analogues to characterize the facies change through the tidal-fluvial transition. Presents the latest outcomes from recent, large, integrated field programs in estuaries around the world Gives detailed field descriptions (outcrop, borehole, core, contemporary sediments) of tidal-fluvial deposits Accesses new models and validation datasets for estuarine processes and deposits Presents descriptions of contemporary environments and ancient outcrop analogues to characterize the facies change through the tidal-fluvial transition
Download or read book Reservoir Characterization and Its Application to Improved Oil Recovery from the Cypress Formation Mississippian at Richview Field Washington County Illinois written by John P. Grube and published by . This book was released on 1999 with total page 48 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Reservoir Characterization and Improved Oil Recovery from Multiple Bar Sandstones Cypress Formation Tamaroa and Tamaroa South Fields Perry County Illinois written by John P. Grube and published by . This book was released on 1992 with total page 80 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Reservoir Heterogeneity and Potential for Improved Oil Recovery Within the Cypress Formation at Bartelso Field Clinton County Illinois written by Stephen T. Whitaker and published by . This book was released on 1992 with total page 58 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 23 pages. Available in PDF, EPUB and Kindle. Book excerpt: This chapter discusses about these interactions between alkali and surfactant: (1) addition of an alkali in a surfactant solution equivalently adds salt; (2) addition of an alkali in a surfactant solution changes the surfactant phase behavior; and (3) addition of an alkali in a surfactant solution reduces surfactant adsorption. After presenting those fundamentals, two field pilots are presented: Big Sinking field in East Kentucky and White Castle field in Louisiana.
Download or read book Impact of Rock fluid and Fluid fluid Interactions in Chemical Flooding written by Eric Austin Sundstrom and published by . This book was released on 2011 with total page 123 pages. Available in PDF, EPUB and Kindle. Book excerpt: Chemical flooding has been researched extensively for the purposes of enhancing oil recovery. Alkaline-polymer (AP) and alkaline-surfactant-polymer (ASP) injections both rely heavily on similar chemical components. The alkali can reduce interfacial tension (IFT) by reactions with the organic acids of the oil, reduce adsorption of surfactants, and alter wettability. The polymer agent increases the viscosity of the injected aqueous phase to attain a more favorable water-oil mobility ratio. The addition of an alkali to a straight polymer flood can further increase the efficiency in polymer flooding. The alkali can react with the rock, or minerals in the rock, to reduce polymer adsorption. The alkali can also interact with the polymer solution to decrease viscosity, allowing higher injectivity. These and other fluid-fluid and rock-fluid reactions have a significant impact on the performance of a chemical flood. Several core flooding experiments were run to compare oil recovery, resistance factors, and pressure differentials, for polymer, alkali, and AP tertiary floods. The conditions tested correspond to Wyoming's Minnelusa sandstone reservoirs. Berea sandstone cores were waterflooded to residual oil saturation, followed by a tertiary injection of either polymer, alkali, or AP solution, then finished with waterflooding. Two different alkalis, NaOH and Na2CO3 were used and compared for all experiments with alkali. Both single and two phase experiments were conducted to investigate oil recovery and rock-fluid interactions. Rheological experiments were conducted on polymer solutions varying the pH and ionic strength. IFT was measured using pendant-drop shape analysis. The adsorption of the polymer solutions was measured for dynamic and static conditions both with and without the alkalis. The results show that the addition of an alkali can increase oil recovery in both waterflooding and polymer flooding, but has a far more significant impact on the latter as a result of the rock-fluid and fluid-fluid interactions. The alkali addition to a polymer flood, or an AP injection, can decrease viscosity and adsorption of the polymer solution while increasing oil recovery. The decrease in viscosity can lead to an increase in injectivity, more favorable for field applications. As alkali concentration decreases through adsorption and reactions, polymer viscosity increases with the consequent restoration of a more favorable mobility ratio. The decrease in adsorption can also allow for a more economical flood design. The outcomes of this research may further improve chemical flood designs with the addition of an alkali to better understand recovery and injectivity due to the rock-fluid and fluid-fluid interactions when an alkali is one component of a chemical flood. Some of the conclusions of this work can be extended to other alkaline floods such as alkaline-surfactant-polymer injection.
Download or read book Formation Water Chemistry and Modeling of Fluid rock Interaction for Improved Oil Recovery in Aux Vases and Cypress Formations Illinois Basin written by Ilham Demir and published by . This book was released on 1995 with total page 70 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 21 pages. Available in PDF, EPUB and Kindle. Book excerpt: This chapter presents models of wettability alteration using surfactants and upscaling models related to oil recovery in fractured carbonate reservoirs. Chemicals used in carbonate reservoirs are reviewed. The presented field cases where surfactants were used to stimulate oil recovery are the Mauddud carbonate in Bahrain, the Yates field and the Cretaceous Upper Edwards reservoir in Texas, the Cottonwood Creek field in Wyoming, and the Baturaja formation in the Semoga field in Indonesia.
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).
Download or read book Low Salinity and Engineered Water Injection for Sandstone and Carbonate Reservoirs written by Emad Walid Al Shalabi and published by Gulf Professional Publishing. This book was released on 2017-06-14 with total page 179 pages. Available in PDF, EPUB and Kindle. Book excerpt: Low Salinity and Engineered Water Injection for Sandstone and Carbonate Reservoirs provides a first of its kind review of the low salinity and engineered water injection (LSWI/EWI) techniques for today’s more complex enhanced oil recovery methods. Reservoir engineers today are challenged in the design and physical mechanisms behind low salinity injection projects, and to date, the research is currently only located in numerous journal locations. This reference helps readers overcome these challenging issues with explanations on models, experiments, mechanism analysis, and field applications involved in low salinity and engineered water. Covering significant laboratory, numerical, and field studies, lessons learned are also highlighted along with key areas for future research in this fast-growing area of the oil and gas industry. After an introduction to its techniques, the initial chapters review the main experimental findings and explore the mechanisms behind the impact of LSWI/EWI on oil recovery. The book then moves on to the critical area of modeling and simulation, discusses the geochemistry of LSWI/EWI processes, and applications of LSWI/EWI techniques in the field, including the authors’ own recommendations based on their extensive experience. It is an essential reference for professional reservoir and field engineers, researchers and students working on LSWI/EWI and seeking to apply these methods for increased oil recovery. Teaches users how to understand the various mechanisms contributing to incremental oil recovery using low salinity and engineering water injection (LSWI/EWI) in sandstones and carbonates Balances guidance between designing laboratory experiments, to applying the LSWI/EWI techniques at both pilot-scale and full-field-scale for real-world operations Presents state-of-the-art approaches to simulation and modeling of LSWI/EWI
Download or read book Surfactant enhanced Alkaline Flooding Field Project written by and published by . This book was released on 1991 with total page 29 pages. Available in PDF, EPUB and Kindle. Book excerpt: The Tucker sand of Helper (KS) field is a candidate for surfactant-enhanced alkaline flooding. The geology of the Helper site is typical of many DOE Class I reservoirs. The Tucker sand of Helper field was deposited in a fluvial dominated deltaic environment. Helper oil can be mobilized with either chemical system 2 or chemical system 3, as described in this report. Oil fields in the Gulf Coast region are also good candidates for surfactant-enhanced alkaline flooding. The results from laboratory tests conducted in Berea sandstone cores with oil brine from Helper (KS) field are encouraging. The crude oil is viscous and non-acidic and, yet, was mobilized by the chemical formulations described in this report. Significant amounts of the oil were mobilized under simulated reservoir conditions. The results in Berea sandstone cores were encouraging and should be verified by tests with field core. Consumption of alkali, measured with field core, was very low. Surfactant loss appeared to be acceptable. Despite the good potential for mobilization of Helper oil, certain reservoir characteristics such as low permeability, compartmentalization, and shallow depth place constraints on applications of any chemical system in the Tucker sand. These constraints are typical of many DOE Class I reservoirs. Although Hepler field is not a perfect reservoir in which to apply surfactant- enhanced alkaline flooding, Hepler oil is particularly amenable to mobilization by surfactant-enhanced alkaline systems. A field test is recommended, dependent upon final evaluation of well logs and cores from the proposed pilot area. 14 refs., 21 figs., 10 tabs.
Download or read book Simulation Study to Investigate the Effect of Natural Fractures on the Performance of Surfactant polymer Flood in Carbonate Reservoirs written by Nawaf Ibrahim A. Sayedakram and published by . This book was released on 2011 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: This thesis presents a comprehensive simulation study on the impact of natural fractures on the performance of surfactant polymer flood in a field scale surfactant-polymer flood. The simulation model utilized for the study is a dual porosity dual permeability model representing 1/8 of a 20-acre 5-spot pattern. The model parameters studied include wettability alteration, IFT changes and mobility reduction effect. The results of this study clearly indicate the importance of reservoir description and fracture modeling for a successful surfactant-polymer flood. Naturally fractured carbonate reservoirs are usually characterized by mixed wettability and low matrix permeability which leads to low oil recovery and high remaining oil saturation. Enhanced oil recovery methods such as surfactant-polymer flood (SPF) enhance the recovery by increasing the spontaneous imbibitions either by lowering the interfacial tension or altering the wettability. However, one of the main reasons for failed surfactant-polymer floods is under-estimating the importance of the reservoir especially the description of natural fractures and their effect on recovery. Sensitivity runs were made to compare oil recovery capillary force, buoyancy force and viscous force. The simulation study indicates that critical water saturation should be reached before the start of surfactant-polymer flood to maximize oil recovery and utilize the capillary force. Also, when a surfactant alters the rock wettability, an optimum IFT should be identified for faster and higher imbibitions. The study shows that a contrast in permeability between that of the fracture and that of the matrix will result in a slightly lower oil recovery. Having the fracture perpendicular to the injector producer will result in a higher areal sweep and lower residual oil. A sensitivity study on the effect of the size of surfactant polymer slug was not conclusive. Maximum adsorption capacity was reached which was one of the causes of low imbibitions rate. Following the surfactant-polymer with water flood was able to reverse the adsorption and restore some of the movable oil. The results show that if the enhanced fluid that alter the wettability, imbibed in the matrix, injecting high IFT brine will increase the rate of imbibition. The study calls for further investigation of this phenomenon through research using a scaled laboratory model to verify the simulation results.
Download or read book Surfactant enhanced Alkaline Flooding Field Project Annual Report Revision written by and published by . This book was released on 1991 with total page 29 pages. Available in PDF, EPUB and Kindle. Book excerpt: The Tucker sand of Helper (KS) field is a candidate for surfactant-enhanced alkaline flooding. The geology of the Helper site is typical of many DOE Class I reservoirs. The Tucker sand of Helper field was deposited in a fluvial dominated deltaic environment. Helper oil can be mobilized with either chemical system 2 or chemical system 3, as described in this report. Oil fields in the Gulf Coast region are also good candidates for surfactant-enhanced alkaline flooding. The results from laboratory tests conducted in Berea sandstone cores with oil brine from Helper (KS) field are encouraging. The crude oil is viscous and non-acidic and, yet, was mobilized by the chemical formulations described in this report. Significant amounts of the oil were mobilized under simulated reservoir conditions. The results in Berea sandstone cores were encouraging and should be verified by tests with field core. Consumption of alkali, measured with field core, was very low. Surfactant loss appeared to be acceptable. Despite the good potential for mobilization of Helper oil, certain reservoir characteristics such as low permeability, compartmentalization, and shallow depth place constraints on applications of any chemical system in the Tucker sand. These constraints are typical of many DOE Class I reservoirs. Although Hepler field is not a perfect reservoir in which to apply surfactant- enhanced alkaline flooding, Hepler oil is particularly amenable to mobilization by surfactant-enhanced alkaline systems. A field test is recommended, dependent upon final evaluation of well logs and cores from the proposed pilot area. 14 refs., 21 figs., 10 tabs.
