Download or read book Effect of Flood Advance Rate and Micellar Solution Slug Size on Tertiary Oil Recovery in Oil wet and Water wet Systems written by Suleiman Mohammad Shamsaldeen and published by . This book was released on 1979 with total page 186 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 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 Commercial scale demonstration enhanced oil recovery by micellar polymer flood written by Marathon Oil Company and published by . This book was released on 1978 with total page 88 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Petroleum Abstracts written by and published by . This book was released on 1981-04 with total page 884 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Contracts and Grants for Cooperative Research on Enhanced Oil and Gas Recovery and Improved Drilling Methods Progress Review written by United States. Dept. of Energy and published by . This book was released on 1980 with total page 670 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Micellar Flooding of Bonnie Glen Crude written by Ronald A. Daharu and published by . This book was released on 1984 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Phase behaviour studies were conducted to determine micellar slug compositions miscible with Bonnie Glen Crude and brine. Berea sandstone cores 61/122 cm in length were saturated with oil and waterflooded to residual oil saturation. Micellar polymer floods were then initiated to evaluate the effectiveness of the various slugs in recovering tertiary oil. Effluent samples were collected and analyzed to determine sulfonate recovery. Tertiary oil recovery for all micellar slugs evaluated was greater than 65% of the oil in place. Core floods were conducted at various frontal velocities to determine its effect on tertiary oil recovery. Oil recovery increased with increasing velocity up to a point then decreased with increasing velocity. This decrease in oil recovery was largely due to fingering of the polymer solution through the micellar slug. Surfactant loss was found to be dependent on the micellar slug composition and the mineralogical composition of the sandstone. Cosurfactants such as n-Butyl alcohol and iso-propyl alcohol reduced sulfonate losses significantly. X-ray analysis of the Berea cores revealed the presence of illite, chlorite and kaolinite. Although the clay mineral content of the cores was only 1-3% of the matrix , because of the large surface area and high reactivity, they were partly responsible for the deactivation of the micellar slug. In order to reduce sulfonate losses, various preflush solutions were injected prior to injection of the micellar slug. Preflushes consisting of 1% by weight sodium carbonate and 1% by weight ethylenediaminetetracetic acid (EDTA) were found to be the most effective. Sodium carbonate preflushes increased tertiary oil recovery by reducing oil/water interfacial tension and sulfonate losses. EDTA preflushes protected the micellar slug by forming metallic complexes with the multivalent cations.For a given size EDTA preflush, adjusting the pH to 11.4 resulted in a further increase in tertiary oil recovery. Lignosulfonate solutions were found to be ineffective preflushes; while aqueous solutions of Petrostep 465 plugged the cores. For the system under study,-displacement was initially miscible but as the micellar slug moved through the cores, mixing and sulfonate loss resulted in the displacement reverting to immiscible type displacement.
Download or read book Energy Research Abstracts written by and published by . This book was released on 1990 with total page 852 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Research Publications and Professional Activities written by Pennsylvania State University and published by . This book was released on 1977 with total page 792 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Effect of Oil Viscosity on the Recovery of Oil by Water Flooding written by A. N. Fried and published by . This book was released on 1955 with total page 42 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Improved Oil Recovery by Surfactant and Polymer Flooding written by D.O. Shah and published by Elsevier. This book was released on 2012-12-02 with total page 589 pages. Available in PDF, EPUB and Kindle. Book excerpt: Improved Oil Recovery by Surfactant and Polymer Flooding contains papers presented at the 1976 AIChE Symposium on Improved Oil Recovery by Surfactant and Polymer Flooding held in Kansas City. Organized into 18 chapters, the book includes papers that introduce petroleum reservoirs and discuss interfacial tension; molecular forces; molecular aspects of ultralow interfacial tension; the structure, formation, and phase inversion of microemulsions; and thermodynamics of micellization and related phenomena. Papers on adsorption phenomena at solid/liquid interfaces and reservoir rocks, as well as on flow through porous media studies on polymer solutions, microemulsions, and soluble oils are also provided. Significant topics on molecular, microscopic, and macroscopic aspects of oil displacement in porous media by surfactant and polymer solutions and related phenomena are also discussed. The literature cited in this book forms a comprehensive list of references in relation to improved oil recovery by surfactant and polymer flooding. This book will be useful to experts and non-experts in this field of research.
Download or read book Standard Handbook of Petroleum and Natural Gas Engineering written by William C. Lyons and published by Elsevier. This book was released on 2011-03-15 with total page 1564 pages. Available in PDF, EPUB and Kindle. Book excerpt: This new edition of the Standard Handbook of Petroleum and Natural Gas Engineering provides you with the best, state-of-the-art coverage for every aspect of petroleum and natural gas engineering. With thousands of illustrations and 1,600 information-packed pages, this text is a handy and valuable reference. Written by over a dozen leading industry experts and academics, the Standard Handbook of Petroleum and Natural Gas Engineering provides the best, most comprehensive source of petroleum engineering information available. Now in an easy-to-use single volume format, this classic is one of the true "must haves" in any petroleum or natural gas engineer's library. A classic for the oil and gas industry for over 65 years! A comprehensive source for the newest developments, advances, and procedures in the petrochemical industry, covering everything from drilling and production to the economics of the oil patch Everything you need - all the facts, data, equipment, performance, and principles of petroleum engineering, information not found anywhere else A desktop reference for all kinds of calculations, tables, and equations that engineers need on the rig or in the office A time and money saver on procedural and equipment alternatives, application techniques, and new approaches to problems
Download or read book Dynamic Capillary Phenomena in Oil Recovery by Water Flooding written by Howard Hulen Ferrell and published by . This book was released on 1961 with total page 108 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Earth and Mineral Sciences written by and published by . This book was released on 1979-10 with total page 76 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Effect of Changing Injection Water Salinity on Oil Recovery from Oil wet Carbonate Rocks written by Ugur Pakoz and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Experimental studies and some field applications have shown that tuning the salinity of the injected water can affect oil recovery from water flooding. Most of the available literature has dedicated efforts to investigate the effect of low salinity water injection, especially for sandstone. Further studies on carbonate rocks also proved that low salinity effect might be observed for carbonate rocks as well. The main mechanism for the improved oil recovery from low salinity water flooding has been attributed to wettability alteration. The purpose of this work is to further investigate the effect of water salinity on oil recovery from oil-wet carbonate rocks. A series of core flood experiments were performed in the laboratory to measure and compare oil recovery from increasing and decreasing salinity floods at room temperature. Selected carbonate cores were aged with synthetic oil at 100 oC for 12 days prior to core flooding. Contact angles were measured on pre-aged and post-aged core slices to validate aging procedure and oil-wet conditions. Both, increasing and decreasing salinity floods showed measurable recovery gains in the secondary and tertiary modes compared with initial floods. In case of increasing water salinity, 1.3% and 0.6% additional recoveries were obtained while in the case of decreasing water salinity, additional recoveries were 0.6% and 0.7%, all in terms of original oil in place in the core. Results suggest that the system disturbance caused by the change in injection water salinity may have a greater influence on oil recovery than wettability alteration under the laboratory conditions tested.
Download or read book Experiments and Modeling of Wettability Alteration in Low Permeability Porous Media written by Prateek Kathel and published by . This book was released on 2015 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Naturally fractured reservoirs contain a significant amount of global hydrocarbon reserves. In fractured reservoirs, the efficiency of water flood is governed by spontaneous imbibition of water into oil-containing matrix blocks. When the matrix is oil-wet or mixed-wet, little oil can be recovered by imbibition. Wettability alteration provides a possible solution to enhance oil recovery in oil/mixed-wet fractured formations. Different chemicals such as surfactants, enzymes, selective ions can be used to alter wettability from oil-wet towards more water-wet which can substantially increase the oil recovery. Understanding recovery mechanisms for these processes at different inverse bond numbers (ratio of capillary to buoyancy forces) and developing scaling rules are critical for estimating feasibility at field scale. Surfactants were identified which altered the wettability of a low permeability (0.03 - 0.23 mD) mixed-wet/oil-wet sandstone reservoir. Static imbibition experiments in the surfactant solution resulted in high oil recovery (42-68% OOIP) compared to 15% OOIP in formation brine. High (>240) inverse bond numbers for these experiments indicate recovery mechanism as counter-current imbibition driven by capillary forces. Numerically simulated saturation and velocity profiles on validated datasets were analyzed to study the recovery mechanisms. Velocity profiles indicate counter current flows with velocity vectors pointing outwards. Similar visual observations were made during experiments, which were captured through images. The saturation front moves radially inward with symmetric profiles at the top and bottom. An analysis of scaling laws for the capillary driven flow suggests that imbibition recovery curves do not correlate with traditional scaling groups (Mattax and Kyte, 1962; Ma et al. 1997). The scaling equations analyzed are for strongly water-wet porous media and are insufficient to explain the dynamics of changing wettability from oil-wet to water-wet. The recovery data shows that oil recovery varies linearly with square root of time. It was observed that the rate of recovery was higher for the higher IFT cases in experiments performed on cores with almost same initial oil saturation using the same surfactant, but at different salinities. As a result of varying the salinity, interfacial tension between oil/water is varied. To evaluate the application of wettability altering processes at larger scales experiments were performed on outcrop cores of different dimensions and at dynamic conditions. Surfactant formulation was developed which altered the wettability from oil-wet to water-wet on outcrop rocks Estaillades Limestone and Texas Cream Limestone. Using the surfactant formulation static and dynamic imbibition experiments were performed on cores with different dimensions and boundary conditions. It is observed that dynamic imbibition process recovers oil faster than static imbibition. Imbibition experiments performed on cores with varying height and diameter show that oil recovery decreases with increasing diameter and height. Study of numerically simulated velocity and saturation profile on validated input datasets established the recovery mechanism as gravity dominated flow. Analytical scaling groups for gravity dominated flow were tested considering pressure drop only in water phase, pressure drop only in oil phase, and pressure drop across both water and oil phases. The model with pressure drop in both phases captures the decrease in recovery with increase in diameter and height of the core. Sensitivity to change in oil recovery with change in height is fairly accurate whereas the model over-predicts oil recovery with change in diameter. A new space-time scaling function (t/DH) is proposed for surfactant aided gravity dominated processes. Data with same boundary conditions, rock, fluids and varying dimensions can be correlated with the scaling function at early times with no fitting parameters involved. A good correlation is obtained with the data from different studies indicating the effectiveness of the scaling function. The scaling is applicable to both static as well as dynamic imbibition cases. Corefloods were performed on cores from different reservoirs to study the effect of wettability altering surfactant flood in a viscous pressure gradient driven process (as opposed to capillary or buoyancy driven imbibition process). Incremental oil recoveries over waterflood were analyzed for different injection schemes. Incremental recoveries over waterflood of 16% and 11% were obtained for secondary surfactant flood and slug process (surfactant slug injection after short initial waterflood) respectively for carbonate reservoir 1. Similarly, incremental recoveries over waterflood of 11% and 7% were obtained for secondary surfactant flood and slug process respectively for carbonate reservoir 2. The incremental oil recovery due to surfactant injection is attributed to the favorable increase in the relative permeability values of oil as the wettability is changed from oil-wet to water-wet. Experiments indicate that surfactant performance at the reservoir conditions (temperature, salinity, heterogeneity) is a key variable in these processes. Despite the differences in these conditions, for both the reservoirs oil recovery is more in the secondary surfactant injection mode compared to the slug process.
Download or read book Effect of Wettability of Porous Media on Oil Recovery by Water Flood written by I. L. Budhiraja and published by . This book was released on 1964 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: As a result of water flood studies made on a long unconsolidated core consisting of a pack of glass spheres, it has been found that break through recovery decreases by about 16 per cent as the wettability of the pack is changed from preferentially water wet to preferentially oil wet. This change in wettability has been brought about by treating the glass spheres with dilute solutions of Dri-film in benzene. The ultimate recovery has also been found to decrease as the oil wetness of the porous medium increases. The degree of wettability of the porous medium has been estimated by carrying out contact angle measurements in glass capillary tubes. An attempt has been made to establish the same wetting conditions in the capillary tubes as in the porous medium. This has been done by keeping the ratio of the volume of the treating liquid to the surface area treated, approximately the same in both.
