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The Petroleum Technology Transfer Council (PTTC) was established by domestic crude oil and natural gas producers, working in conjunction with the Independent Petroleum Association of America (IPAA), the U.S. Department of Energy (...
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The Petroleum Technology Transfer Council (PTTC) was established by domestic crude oil and natural gas producers, working in conjunction with the Independent Petroleum Association of America (IPAA), the U.S. Department of Energy (DOE) and selected universities, in 1994 as a national not-for-profit organization. Its goal is to transfer Exploration and Production (E&P) technology to the domestic upstream petroleum industry, in particular to the small independent operators. PTTC connects producers, technology providers and innovators, academia, and university/industry/government research and development (R&D) groups. From inception PTTC has received federal funding through DOE's oil and natural gas program managed by the National Energy Technology Laboratory (NETL). With higher funding available in its early years, PTTC was able to deliver well more than 100 workshops per year, drawing 6,000 or more attendees per year. Facing the reality of little or no federal funding in the 2006-2007 time frame, PTTC and the American Association of Petroleum Geologists (AAPG) worked together for PTTC to become a subsidiary organization of AAPG. This change brings additional organizational and financial resources to bear for PTTC's benefit. PTTC has now been 'powered by AAPG' for two full fiscal years. There is a clear sense that PTTC has stabilized and is strengthening its regional workshop and national technology transfer programs and is becoming more entrepreneurial in exploring technology transfer opportunities beyond its primary DOE contract. Quantitative accomplishments: PTTC has maintained its unique structure of a national organization working through Regional Lead Organizations (RLOs) to deliver local, affordable workshops. During the contract period PTTC consolidated from 10 to six regions efficiency and alignment with AAPG sections.
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A stable optical reference oscillator (SORO) consisting of conventional low power CW source of coherent optical radiation having a relatively narrow bandwidth is mixed, i.e., beat against a sample of an incoherent laser transmit s...
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A stable optical reference oscillator (SORO) consisting of conventional low power CW source of coherent optical radiation having a relatively narrow bandwidth is mixed, i.e., beat against a sample of an incoherent laser transmit signal and the phase of the resultant signal is recorded. This is then compared to the phase of an ideal pulse of a perfect laser transmitter which was previously generated and recorded. The result is a phase correction term which is used in the subsequent signal processing of the received signals to realign the received laser pulses so that they are phase coherent.
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The purpose of this paper is to compelling delineate how the lessons learned from Grant's successful integration of Land and Naval Power shed light on the issue of Strategic Vision. The Strategic Vision clearly demonstrated by Gra...
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The purpose of this paper is to compelling delineate how the lessons learned from Grant's successful integration of Land and Naval Power shed light on the issue of Strategic Vision. The Strategic Vision clearly demonstrated by Grant during the Vicksburg Campaign provides valuable lessons for the application of future joint operations. The Vicksburg Campaign shows the acumen, vision, and the requisite leadership traits of General Ulysses S. Grant as he effectively collaborated with Admiral David D. Porter, the Commander of the Naval Forces, and his principal subordinate, General William T. Sherman to implement the paramount Strategic objective for the Western Theater-to seize Vicksburg and gain control of the Mississippi River. This analysis reveals five important lessons essential for successful joint operations. First, Land and Naval Power success on the battlefield requires close cooperation and synchronization of effort by the Joint Commanders.
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The Department of Energy's (DOE's) primary mission in the oil research program is to maximize the economically and environmentally sound recovery of oil from domestic reservoirs and to preserve access to this resource. The Oil Rec...
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The Department of Energy's (DOE's) primary mission in the oil research program is to maximize the economically and environmentally sound recovery of oil from domestic reservoirs and to preserve access to this resource. The Oil Recovery Field Demonstration Program supports DOE's mission through cost-shared demonstrations of improved Oil Recovery (IOR) processes and reservoir characterization methods. In the past 3 years, the DOE has issued Program Opportunity Notices (PONs) seeking cost-shared proposals for the three highest priority, geologically defined reservoir classes. The classes have been prioritized based on resource size and risk of abandonment. This document defines the geologic, reservoir, and production characteristics of the fourth reservoir class, strandplain/barrier islands. Knowledge of the geological factors and processes that control formation and preservation of reservoir deposits, external and internal reservoir heterogeneities, reservoir characterization methodology, and IOR process application can be used to increase production of the remaining oil-in-place (IOR) in Class 4 reservoirs. Knowledge of heterogeneities that inhibit or block fluid flow is particularly critical. Using the TORIS database of 330 of the largest strandplain/barrier island reservoirs and its predictive and economic models, the recovery potential which could result from future application of IOR technologies to Class 4 reservoirs was estimated to be between 1.0 and 4.3 billion barrels, depending on oil price and the level of technology advancement. The analysis indicated that this potential could be realized through (1) infill drilling alone and in combination with polymer flooding and profile modification, (2) chemical flooding (sufactant), and (3) thermal processes. Most of this future potential is in Texas, Oklahoma, and the Rocky Mountain region. Approximately two-thirds of the potentially recoverable resource is at risk of abandonment by the year 2000.
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This report identifies reservoir characterization and reservoir management research needs and IOR process and related research needs for the fourth geologic class, strandplain/barrier island reservoirs. The 330 Class 4 reservoirs ...
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This report identifies reservoir characterization and reservoir management research needs and IOR process and related research needs for the fourth geologic class, strandplain/barrier island reservoirs. The 330 Class 4 reservoirs in the DOE Tertiary OH Recovery Information System (TORIS) database contain about 30.8 billion barrels of oil or about 9% of the total original oil-in-place (OOIP) in all United States reservoirs. The current projection of Class 4 ultimate recovery with current operations is only 38% of the OOIP, leaving 19 billion barrels as the target for future IOR projects. Using the TORIS database and its predictive and economic models, the recovery potential which could result from future application of IOR technologies to Class 4 reservoirs was estimated to be between 1.0 and 4.3 billion barrels, depending on oil price and the level of technology advancement. The analysis indicated that this potential could be realized through (1) infill drilling alone and in combination with polymer flooding and profile modification, (2) chemical flooding (surfactant), and (3) thermal processes. Most of this future potential is in Texas, Oklahoma, California, and the Rocky Mountain region. Approximately two-thirds of the potentially recoverable resource is at risk of abandonment by the year 2000, which emphasizes the urgent need for the development and demonstration of cost-effective recovery technologies.
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A commercial scale low-tension flood (micellar-polymer) demonstration project was conducted in the Second Wall Creek Reservoir in the Big Muddy Field in east central Wyoming. The cost-shared, low-tension flood used a 0.1 pore volu...
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A commercial scale low-tension flood (micellar-polymer) demonstration project was conducted in the Second Wall Creek Reservoir in the Big Muddy Field in east central Wyoming. The cost-shared, low-tension flood used a 0.1 pore volume preflush and a 0.1 pore volume low-tension slug followed by a polymer drive bank. The sulfonate used in the low-tension slug was a blend of both low and high molecular weight synthetic sulfonates. Dow Pusher 500, a dry polyacrylamide polymer, was used in both the low-tension slug and polymer drive bank for mobility control. Although project oil recovery was or will be significantly less than originally predicted, the low-tension process successfully mobilized waterflood residual oil. The primary factor contributing to lower than anticipated recovery was lack of containment of the injected fluids in the reservoir. Behind-pipe communication in abandoned or reconditioned wellbores in the project area represented the most probable source of fluid migration from the reservoir. Fluid entry from other reservoirs occurred concurrently with migration of the fluids from the reservoir. Fluid containment deteriorated significantly when injection pressures during the polymer injection period were allowed to exceed the formation parting pressure. Injectivity in the relatively low permeability reservoir was a continuing operational problem. 6 refs., 78 figs., 19 tabs. (ERA citation 14:012567)
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A commercial scale micellar-polymer project was conducted in the Robinson Sand of the M-1 project in southwestern Illinois. The project utilized a crude oil sulfonate surfactant system to flood the reservoir which, at the time of ...
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A commercial scale micellar-polymer project was conducted in the Robinson Sand of the M-1 project in southwestern Illinois. The project utilized a crude oil sulfonate surfactant system to flood the reservoir which, at the time of the project, was in an advanced stage of waterflood depletion. Injected fluids consisted of a 0.10 pore volume crude oil sulfonate slug, a 1.05 pore volume graded mobility slug using Dow Pusher 700, and a drive water slug to depletion. Micellar injection started in 1977. By December, 1986, overall operations in the 2.5-acre pattern area were uneconomical while polymer injection was continuing in the 5.0-acre pattern area. Depletion of the 5.0-acre pattern area is forecast for 1991 or sooner. Ultimate oil recovery is estimated at 1,397,000 barrels with cumulative oil recovery at December, 1986, of 1,299,000 barrels. Although the crude oil sulfonate system successfully mobilized and produced waterflood residual oil, the project was not economic because of both lower than anticipated recovery and higher than expected operating costs. The lower than anticipated recovery is attributed to poor volumetric sweep efficiency and salinity/hardness effects. 7 refs., 54 figs., 25 tabs. (ERA citation 14:012568)
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Information obtained from twelve pilots flying a C-47 aircraft at night using three different instrument lighting systems is presented. These systems were: (1) Red Flood, (2) Indirect Red, and (3) Ultra-Violet. Brightness levels u...
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Information obtained from twelve pilots flying a C-47 aircraft at night using three different instrument lighting systems is presented. These systems were: (1) Red Flood, (2) Indirect Red, and (3) Ultra-Violet. Brightness levels used by the pilots were recorded for the three systems under varying flying conditions. These conditions were (1) normal night flying, (2) night instrument (maximum), and (3) minimum brightness necessary for safe flight. For normal conditions the lowest brightness level used occurred under Red Flood and highest under Indirect Red. At minimum levels Indirect Red was lowest followed by Ultra-Violet and Red Flood. At maximum levels (night instrument condition) Red Flood was highest, Indirect Red next and Ultra-Violet the lowest although this position of Ultra-Violet represented the maximum available brightness range for this system. Pilot opinion showed varying preferences for the different conditions. Indirect Red was preferred as being the most pleasant and comfortable system and Red Flood was preferred as being the most effective of the three.
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