The Experts below are selected from a list of 321 Experts worldwide ranked by ideXlab platform
Gregory F. Ulmishek - One of the best experts on this subject based on the ideXlab platform.
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Reserve Growth in Oil Fields of West Siberian Basin, Russia
Natural Resources Research, 2003Co-Authors: Mahendra K. Verma, Gregory F. UlmishekAbstract:Although reserve (or field) growth has proved to be an important contributing factor in adding new reserves in mature petroleum basins, it is a poorly understood phenomenon. Although several papers have been published on the U.S. Fields, there are only a few publications on Fields in other petroleum provinces. This paper explores the reserve growth in the 42 largest West Siberian Oil Fields that contain about 55% of the basin's total Oil reserves. The West Siberian Oil Fields show 13-fold reserve growth 20 years after the discovery year and only about 2-fold growth after the first production year. This difference in growth is attributed to extensive exploration and field delineation activities between discovery and the first production year. Because of the uncertainty in the length of evaluation time and in reported reserves during this initial period, reserve growth based on the first production year is more reliable for model development. However, reserve growth models based both on discovery year and first production year show rapid growth in the first few years and slower growth in the following years. In contrast, the reserve growth patterns for the conterminous United States and offshore Gulf of Mexico show a steady reserve increase throughout the productive lives of the Fields. The different reserve booking requirements and the lack of capital investment for improved reservoir management and production technologies in West Siberia are the probable causes for the difference in the growth patterns. The models based on the first production year predict that the reserve growth potential in the 42 largest Oil Fields of West Siberia for a five-year period (1998–2003) ranges from 270–330 million barrels or 0.34–0.42% per year. For a similar five-year period (1996–2001), models for the conterminous United States predict a growth of 0.54–0.75% per year.
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reserve growth in Oil Fields of west siberian basin russia
Natural resources research, 2003Co-Authors: Mahendra K. Verma, Gregory F. UlmishekAbstract:Although reserve (or field) growth has proved to be an important contributing factor in adding new reserves in mature petroleum basins, it is a poorly understood phenomenon. Although several papers have been published on the U.S. Fields, there are only a few publications on Fields in other petroleum provinces. This paper explores the reserve growth in the 42 largest West Siberian Oil Fields that contain about 55% of the basin's total Oil reserves.
Mahendra K. Verma - One of the best experts on this subject based on the ideXlab platform.
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Reserve Growth in Oil Fields of West Siberian Basin, Russia
Natural Resources Research, 2003Co-Authors: Mahendra K. Verma, Gregory F. UlmishekAbstract:Although reserve (or field) growth has proved to be an important contributing factor in adding new reserves in mature petroleum basins, it is a poorly understood phenomenon. Although several papers have been published on the U.S. Fields, there are only a few publications on Fields in other petroleum provinces. This paper explores the reserve growth in the 42 largest West Siberian Oil Fields that contain about 55% of the basin's total Oil reserves. The West Siberian Oil Fields show 13-fold reserve growth 20 years after the discovery year and only about 2-fold growth after the first production year. This difference in growth is attributed to extensive exploration and field delineation activities between discovery and the first production year. Because of the uncertainty in the length of evaluation time and in reported reserves during this initial period, reserve growth based on the first production year is more reliable for model development. However, reserve growth models based both on discovery year and first production year show rapid growth in the first few years and slower growth in the following years. In contrast, the reserve growth patterns for the conterminous United States and offshore Gulf of Mexico show a steady reserve increase throughout the productive lives of the Fields. The different reserve booking requirements and the lack of capital investment for improved reservoir management and production technologies in West Siberia are the probable causes for the difference in the growth patterns. The models based on the first production year predict that the reserve growth potential in the 42 largest Oil Fields of West Siberia for a five-year period (1998–2003) ranges from 270–330 million barrels or 0.34–0.42% per year. For a similar five-year period (1996–2001), models for the conterminous United States predict a growth of 0.54–0.75% per year.
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reserve growth in Oil Fields of west siberian basin russia
Natural resources research, 2003Co-Authors: Mahendra K. Verma, Gregory F. UlmishekAbstract:Although reserve (or field) growth has proved to be an important contributing factor in adding new reserves in mature petroleum basins, it is a poorly understood phenomenon. Although several papers have been published on the U.S. Fields, there are only a few publications on Fields in other petroleum provinces. This paper explores the reserve growth in the 42 largest West Siberian Oil Fields that contain about 55% of the basin's total Oil reserves.
M. S. H. Bader - One of the best experts on this subject based on the ideXlab platform.
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seawater versus produced water in Oil Fields water injection operations
Desalination, 2007Co-Authors: M. S. H. BaderAbstract:Maximizing Oil production by water flooding demands injection of water in sufficient quantities and acceptable qualities into the appropriate regions of the reservoirs in a cost efficient manner. The questions are: (1) what is the allowable level of water quality that steadily enhances production?; and (2) is it technically and economically possible to achieve such a level of water quality? In this fifth article, of a five-part series, the effects of water quality and the possibility of inducing unwanted fractures by the combined pressure-temperature stress of the injected water are discussed. The discussion is strictly focused on comparing Oil-Fields produced water to seawater as possible sources for water injection operation.
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sulfate removal technologies for Oil Fields seawater injection operations
Journal of Petroleum Science and Engineering, 2007Co-Authors: M. S. H. BaderAbstract:Abstract Pressure maintenance in Oil Fields through seawater injection is taking place on a massive way throughout the world. In some Oil Fields, the current capacity of seawater injection is well over a million barrels per day (1 barrel of water is equivalent to 42 gal.). The typical incompatibility between Oil Fields formation waters and seawater causes unusual severe sulfate scale problems in the forms of calcium and/or strontium and/or barium. An innovative technology based on the concepts of membrane distillation (MD) and liquid-phase precipitation (LPP) is developed for the selective removal of sulfate from seawater before injection. The advantages of the MD-LPP technology include the: (1) use of a small amount of energy and additive; (2) generation of minimal waste with suitable disposal paths; (3) extraction of economic values from discarded streams or species; and (4) rapid economic deployment. The generated sulfate-free seawater from the MD-LPP technology can be injected safely in Oil Fields for flooding and pressure support. This “proactive” sulfate-free seawater injection approach would prevent sulfate scale problems such as scale deposits, reservoir souring, and adherence of radioactive species at the onset. Such an approach is much more economical than the typical “reactive” approach of deliberately injecting incompatible seawater, and then endlessly, and in most cases unsuccessfully, remediating sulfate scale damages over the life time of producing wells. Further innovative approaches to integrate pressure-driven membranes such as nanofiltration (NF) and reverse osmosis (RO) in conjunction with LPP or compressed-phase precipitation (CPP) to solve their inherent sulfate scale problems in treating seawater for the selective removal of sulfate are also provided.
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Nanofiltration for Oil-Fields water injection operations: analysis of concentration polarization
Desalination, 2006Co-Authors: M. S. H. BaderAbstract:Abstract Nanofiltration (NF) membranes are capable of highly rejecting divalent anions (e.g., sulfate) while retaining a large portion of monovalent anions (e.g., chloride) from seawater. NF is thus a potential technology to provide nearly sulfate-free seawater for Oil Fields water injection operations. However, as the case with any pressure-driven membrane processes, concentration polarization is the most critical problem encountered in NF operation. For proper design and operation of NF for selective removal of sulfate from seawater and the like of saline streams, knowledge of ions concentrations at the membrane surface and on the concentrate side of the membrane is critical. This second article, in a four-part series, provides a modeling tool to analyze the effect concentration polarization phenomena in NF. Such an analysis allows the prediction of the actual rejection (Ra) in the absence of concentration polarization, and the accumulation of rejected ions at the membrane surface (Cm).
M.s. Al-blehed - One of the best experts on this subject based on the ideXlab platform.
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Possible Applications of MEOR to the Arab Oil Fields
Journal of King Saud University: Engineering Sciences, 2018Co-Authors: M.h. Sayyouh, M.s. Al-blehed, Adel M. HemeidaAbstract:Abstract Large quantities of residual Oil will remain in the Arab Oil reservoirs after the primary recovery and water-flooding stages. Because of the large sizes of the Saudi Oil Fields (in particular), the amount of the residual Oil will be enormous. According to the latest published data, the original Oil in-place in Saudi Arabia is about 700 billion barrels. Only around 250 billion barrels, 35% of total Oil in-place, can be produced by conventional production methods. More than 90 billion barrels, as much as twice the proven reserve of the U.S. and Canada combined, can be added to the country’s proven reserve if only 20% out of the 450 billion barrels left in-place are produced through enhanced Oil recovery methods. Any method that can recover a significant part of this residual Oil would be of great importance and should be investigated. Microbial Enhanced Oil Recovery (MEOR) has been recognized as a potentially cost-effective recovery method. This paper is an investigation of the applicability of MEOR for recovering more Oil under the Arab Oil Fields conditions. Based on the analysis of data obtained from more than 300 formations in seven Arab countries (Saudi Arabia, Egypt, Kuwait, Qatar, UAE, Iraq and Syria), the possibility of the application of MEOR to the Arabian area was studied. The basic parameters studied include formation permeability, reservoir pressure and temperature, crude Oil viscosity and API gravity, formation connate water saturation and its salinity. It was found that Saudi, Iraqi and Egyptian Oil Fields can be very good candidates for MEOR processes. Also Qatar, Kuwait and Syria have some potential for MEOR. United Arab Emirates, however, has no potential for MEOR under its reservoir conditions. It is expected that MEOR should recover up to 30% of the residual Oil under the Arab reservoir conditions. The actual recovery, however, can only be determined through laboratory and pilot tests under field conditions. A new technology should be developed in order to be able to apply MEOR succesfully.
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CONTRIBUTION OF HORIZONTAL DRILLING TECHNOLOGY IN THE DEVELOPMENT PROGRAMS OF SAUDI Oil Fields
2001Co-Authors: G. M Hamada, M.s. Al-blehed, M. N. J. Al-awad, M. A. Al-saddiqueAbstract:The technology of drilling and production of horizontal wells is probably one of the most significant breakthrough in the Oil and gas industry of the eighties. The continuous improvement of hardware equipment made horizontal drilling cost-effective technique for developing reserves, improving productivity and recovery in Oil and gas reservoir. This paper is devoted to Saudi experience in horizontal drilling. The last years have been an exciting period for those who believed in horizontal drilling applicability in Saudi Arabia. At the end of the year 1997 over than 150 horizontal wells have been drilled in Saudi Oil Fields. There are four major horizontal well applications identified in Saudi Arabia Oil Fields; 1) Control of coning in relatively thin remaining Oil column area, 2) Improving sweep efficiency of water flooding program, 3) Improving productivity rate in thin/tight reservoirs and 4) Saving in total development costs in conjunction with previous three applications. This paper presents the major areas of application of horizontal wells and more specifically the objectives of applying horizontal drilling in different Saudi Oil Fields and the world horizontal drilling activities along with the Saudi experience will be covered. This paper surveys different field examples to show the application trends of horizontal well technology in both offshore and onshore Oil Fields. The main objective of this survey is to demonstrate the performance improvement of these Oil Fields after the application of horizontal well technology.
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Applications of the Enhanced Recovery Methods to Saudi Oil Fields
Journal of King Saud University - Engineering Sciences, 1992Co-Authors: M.h. Sayyouh, M.s. Al-blehedAbstract:Abstract Based on the analysis of data obtained from 186 Saudi formations, the possibilities of applying different enhanced Oil recovery (EOR) methods were investigated. It was found that the most suitable technical methods applicable to Saudi Oil Fields are the miscible processes using gases. A new technology should be developed in order to be able to apply any of the enhanced recovery methods involving chemicals and heat. A study of the economical feasibility of these methods should also be performed.
S. Mamedova - One of the best experts on this subject based on the ideXlab platform.
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South Caspian Oil Fields: Onshore and Offshore Reservoir Properties
Natural Resources Research, 1999Co-Authors: E. Bagirov, B. Bagirov, Ian Lerche, S. MamedovaAbstract:Original field data reports from the Azerbaijan sector of the South Caspian Basin have been used to compile statistical histograms of reservoir characteristics for both onshore and offshore Oil Fields. Two groups of statistics are presented here: the first group discusses reservoir thickness, areas, volumes, and horizon depths for the onshore and offshore Fields; the second group discusses permeability, porosity, Oil viscosity, Oil recovery factor, reserves, and production for the onshore and offshore Fields. These statistical distributions have been constructed so that one has available an historical database for use in assessing the range of likely reservoir characteristics in exploration ventures in this basin.
