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M.j. Pitts - One of the best experts on this subject based on the ideXlab platform.
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Alkaline-Surfactant-Polymer Technology Potential of the Minnelusa Trend, Powder River Basin
Low Permeability Reservoirs Symposium, 2013Co-Authors: Kon Wyatt, M.j. Pitts, H. Surkalo, Lawrence GriffithAbstract:The Alkaline-Surfactant-Polymer, ASP, process can significantly enhance waterfloods for appropriate reservoirs using carefully designed, reservoir specific, chemical injection strategies. This ASP technology recovers waterflood residual Oil by reducing the capillary forces trapping the Oil and improving the overall contact efficiency. The Minnelusa formation in the Powder River Basin was the location of the first field-wide application of this process in the US. An assessment of this early project nearing the end of its economic life and of other ongoing ASP projects provides an estimate of the potential of the ASP process to add reserves in other Minnelusa fields. Analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the total original Stock Tank Oil in place exceeds one billion barrels. The potential incremental Oil recovery of the ASP process to these fields approaches 130 million barrels. This process can be applied at an incremental cost of $1.60--$3.50/bbl.
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Detailed evaluation of the West Kiehl alkaline-surfactant-polymer field project and its application to mature Minnelusa waterfloods. Final report
1995Co-Authors: M.j. Pitts, H. SurkaloAbstract:The combination of an interfacial tension agent and a mobility control agent has the potential to produce additional Oil beyond a waterflood. The West Kiehl alkaline-surfactant-polymer project is the first application of this chemical enhanced Oil recovery technique. The West Kiehl alkaline-surfactant-polymer flood was initiated in September 1987 as a secondary application after primary recovery. The following analysis of the West Kiehl alkaline-surfactant-polymer flood indicates that incremental Oil greater than waterflooding was produced at a cost of less than $2.00 per incremental barrel. A analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the total original Stock Tank Oil in place exceeds one billion barrels. If the enhanced Oil recovery technology implemented at West Kiehl field could be successfully applied to these fields, the potential incremental Oil recovery would approach 130 million barrels. The goals of ``Detailed Evaluation of the West Kield Alkaline-Surfactant-Polymer Field Project and It`s Application to Mature Minnelusa Waterfloods`` are to evaluate both the field performance of the alkaline-surfactant-polymer enhanced Oil recovery technology as well as its potential application to other Minnelusa Oil fields.
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Detailed evaluation of the West Kiehl alkaline-surfactant-polymer field project and it`s application to mature Minnelusa waterfloods. Annual technical report, January 1993--December 1993
1995Co-Authors: M.j. PittsAbstract:The combination of an interfacial tension agent and a mobility control agent has the potential to produce additional Oil beyond a waterflood. The West Kiehl alkaline-surfactant-polymer project is the most advanced application of this chemical enhanced Oil recovery technique. The West Kiehl alkaline-surfactant-polymer flood was initiated in September 1987 as a secondary application after primary recovery. A preliminary analysis of the West Kiehl alkaline-surfactant-polymer flood indicates that incremental Oil of 20% of the original Stock Tank Oil in place will be produced above waterflooding. The cost of the incremental Oil will be less than $2.50 per incremental barrel. A statistical analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the original Stock Tank Oil in place exceeds one billion barrels. If the enhanced Oil recovery technology implemented at West Kiehl field could be successfully applied to these fields, the potential incremental Oil recovery would approach 200 million barrels. This project (1) evaluates the geological deposition environment of West Kiehl and adjacent Minneluse sand reservoirs; (2) compares the production performance results of the best geologic and reservoir performance analogs and select two fields for future study; (3) compares the two best field analogs to the westmore » Kiehl field using numerical simulation; (4) predict results of applying the enhancement technology on two mature Minneluse waterflood analog units using engineering and numerical simulation; (5) predict waterflood and polymer flood performance of the West Kiehl field using numerical simulation.« less
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Detailed evaluation of the West Kiehl alkaline-surfactant-polymer field project and its application to mature Minnelusa waterfloods. Annual report for the period January 1993--December 1993
1994Co-Authors: M.j. Pitts, H. Surkalo, W.r. MundorfAbstract:The combination of an interfacial tension agent and a mobility control agent has the potential to produce additional Oil beyond a waterflood. The West Kiehl alkaline-surfactant-polymer project is the most advanced application of this chemical enhanced Oil recovery technique. The West Kiehl alkaline-surfactant-polymer flood was initiated in September 1987 as a secondary application after primary recovery. A preliminary analysis of the West Kiehl alkaline-surfactant-polymer flood indicates that incremental Oil of 20% of the original Stock Tank Oil in place will be produced above waterflooding. The cost of the incremental Oil will be less than $2.50 per incremental barrel. A statistical analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the original Stock Tank Oil in place exceeds one billion barrels. If the enhanced Oil recovery technology implemented at West Kiehl field could be successfully applied to these fields, the potential incremental Oil recovery would approach 200 million barrels. {open_quotes}Detailed Evaluation of the West Kiehl Alkaline-Surfactant-Polymer Field Project and Its Application to Mature Minnelusa Waterfloods{close_quotes} objective is to evaluate both the field performance of the alkaline-surfactant-polymer enhanced Oil recovery technology as well as its potential application to other Minnelusa Oil fields.
Abbas Firoozabadi - One of the best experts on this subject based on the ideXlab platform.
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Gas/Oil ratio, temperature, and initial water-saturation effects on solution-gas drive
2020Co-Authors: Ghanshyabhai Tank, Abbas FiroozabadiAbstract:The effects of initial water saturation, S wi , temperature, and gas/Oil ratio (GOR) on solution-gas drive in heavy Oils were studied. The viscosity and gravity of the Stock-Tank Oil used in the tests were 560,000 cp and 8.7°API. In two tests, 4.0 and 5.2% S wi were used. Five tests were conducted at 35°C, and one test was conducted at 46°C.
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Macro- and Microscale Waterflooding Performances of Crudes which form w/o Emulsions upon Mixing with Brines
Energy & Fuels, 2014Co-Authors: Nima Rezaei, Abbas FiroozabadiAbstract:We study the micro- and macroscale waterflooding performances of unusual crudes which naturally form tight emulsions (stable after 15 months) upon mixing with water and different brines—including the reservoir brine. These crudes are obtained from a large Oil field with Stock Tank Oil viscosities in the range 20–100 cP. The waterflooding tests are conducted at constant injection rates in Berea cores and also in a glass-etched micromodel with and without initial water saturation. With the initial water saturation, the emulsions cause final Oil recovery to be significantly lower while the breakthrough is surprisingly suppressed. Pressure data suggests that emulsions are formed in situ in the waterflooding tests both with and without the initial water saturation. The injection pressure data show significant fluctuations after about 3 pore volumes of injection. Both the pressure drop and pressure fluctuations are found to be higher at lower injection rates. Furthermore, the pressure drop is higher in tests wi...
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effect of gor temperature and initial water saturation on solution gas drive in heavy Oil reservoirs
Spe Journal, 2005Co-Authors: G. Tang, Abbas FiroozabadiAbstract:We have carried out an extensive set of tests on solution-gas drive for a heavy Oil to study the effects of initial water saturation, temperature, and gas-Oil ratio (GOR). The viscosity and the API gravity of the Stock-Tank Oil from Hamaca field (in Venezuela) used in our tests are 560,000 cp (at 24°C) and 8.7, respectively. The solution-gas drive tests were conducted using live Oils with solution GOR of 6.5, 9.0, and 12.2 (vol/vol at standard conditions). In two tests, initial water saturations of 4.0 and 5.2% were established. Five tests were conducted at a temperature of 35°C; one test was conducted at 46°C. The duration for each test was approximately 3 months. The following conclusions are drawn based on the results from all the tests. Initial water saturation decreases gas-bubble density. The recovery efficiency decreases because of an increase in gas mobility with increase in initial water saturation. As the temperature increases from 35 to 46°C, the gas relative permeability increases one order of magnitude, which in turn results in a reduction of recovery efficiency. The temperature effect on recovery is in agreement with our previous work with temperature increase from 24 to 35°C. Increase in solution GOR has a significant effect on the gas-bubble nucleation process, mainly because of change in interfacial tension. For all the tests conducted, the Oil recovery by solution-gas drive at test termination was approximately 16% and higher.
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gas Oil ratio temperature and initial water saturation effects on solution gas drive
2001 SPE Annual Technical Conference and Exhibition, 2002Co-Authors: Ghanshyabhai Tank, Abbas FiroozabadiAbstract:The effects of initial water saturation, S wi , temperature, and gas/Oil ratio (GOR) on solution-gas drive in heavy Oils were studied. The viscosity and gravity of the Stock-Tank Oil used in the tests were 560,000 cp and 8.7°API. In two tests, 4.0 and 5.2% S wi were used. Five tests were conducted at 35°C, and one test was conducted at 46°C.
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Pressure and composition effect on wax precipitation : Experimental data and model results
1996Co-Authors: Abbas Firoozabadi, Per FotlandAbstract:Wax precipitation is often studied using the Stock Tank Oil. However, precipitation may be very different in well tubing and production facilities due to the effects of pressure and composition. As an example, the cloudpoint temperature may decrease as much as 15 K from atmospheric pressure to the saturation pressure of 100 bar mostly due to the dissolution of light gases into the Oil (i.e. due to composition changes). It is also often assumed that the addition of solvents such as C 5 and C 6 decreases the cloudpoint temperature. On the contrary, from our modeling results, we have found that the mixing of a crude with a solvent increases the cloudpoint temperature (i.e., enhances the wax precipitation). In this study, the cloundpoint temperature at live Oil conditions and the amount of the precipitated wax at Stock Tank Oil conditions are provided for three crudes. A modified multisolid wax precipitation model is used to study the effects of pressure and composition on wax precipitation. The modeling results reveal that an increase in methane and CO 2 concentration decreases the cloudpoint temperature while an increase in C 5 concentration increases the cloud point temperature.
H. Surkalo - One of the best experts on this subject based on the ideXlab platform.
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Alkaline-Surfactant-Polymer Technology Potential of the Minnelusa Trend, Powder River Basin
Low Permeability Reservoirs Symposium, 2013Co-Authors: Kon Wyatt, M.j. Pitts, H. Surkalo, Lawrence GriffithAbstract:The Alkaline-Surfactant-Polymer, ASP, process can significantly enhance waterfloods for appropriate reservoirs using carefully designed, reservoir specific, chemical injection strategies. This ASP technology recovers waterflood residual Oil by reducing the capillary forces trapping the Oil and improving the overall contact efficiency. The Minnelusa formation in the Powder River Basin was the location of the first field-wide application of this process in the US. An assessment of this early project nearing the end of its economic life and of other ongoing ASP projects provides an estimate of the potential of the ASP process to add reserves in other Minnelusa fields. Analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the total original Stock Tank Oil in place exceeds one billion barrels. The potential incremental Oil recovery of the ASP process to these fields approaches 130 million barrels. This process can be applied at an incremental cost of $1.60--$3.50/bbl.
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Detailed evaluation of the West Kiehl alkaline-surfactant-polymer field project and its application to mature Minnelusa waterfloods. Final report
1995Co-Authors: M.j. Pitts, H. SurkaloAbstract:The combination of an interfacial tension agent and a mobility control agent has the potential to produce additional Oil beyond a waterflood. The West Kiehl alkaline-surfactant-polymer project is the first application of this chemical enhanced Oil recovery technique. The West Kiehl alkaline-surfactant-polymer flood was initiated in September 1987 as a secondary application after primary recovery. The following analysis of the West Kiehl alkaline-surfactant-polymer flood indicates that incremental Oil greater than waterflooding was produced at a cost of less than $2.00 per incremental barrel. A analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the total original Stock Tank Oil in place exceeds one billion barrels. If the enhanced Oil recovery technology implemented at West Kiehl field could be successfully applied to these fields, the potential incremental Oil recovery would approach 130 million barrels. The goals of ``Detailed Evaluation of the West Kield Alkaline-Surfactant-Polymer Field Project and It`s Application to Mature Minnelusa Waterfloods`` are to evaluate both the field performance of the alkaline-surfactant-polymer enhanced Oil recovery technology as well as its potential application to other Minnelusa Oil fields.
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Detailed evaluation of the West Kiehl alkaline-surfactant-polymer field project and its application to mature Minnelusa waterfloods. Annual report for the period January 1993--December 1993
1994Co-Authors: M.j. Pitts, H. Surkalo, W.r. MundorfAbstract:The combination of an interfacial tension agent and a mobility control agent has the potential to produce additional Oil beyond a waterflood. The West Kiehl alkaline-surfactant-polymer project is the most advanced application of this chemical enhanced Oil recovery technique. The West Kiehl alkaline-surfactant-polymer flood was initiated in September 1987 as a secondary application after primary recovery. A preliminary analysis of the West Kiehl alkaline-surfactant-polymer flood indicates that incremental Oil of 20% of the original Stock Tank Oil in place will be produced above waterflooding. The cost of the incremental Oil will be less than $2.50 per incremental barrel. A statistical analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the original Stock Tank Oil in place exceeds one billion barrels. If the enhanced Oil recovery technology implemented at West Kiehl field could be successfully applied to these fields, the potential incremental Oil recovery would approach 200 million barrels. {open_quotes}Detailed Evaluation of the West Kiehl Alkaline-Surfactant-Polymer Field Project and Its Application to Mature Minnelusa Waterfloods{close_quotes} objective is to evaluate both the field performance of the alkaline-surfactant-polymer enhanced Oil recovery technology as well as its potential application to other Minnelusa Oil fields.
W.r. Mundorf - One of the best experts on this subject based on the ideXlab platform.
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Detailed evaluation of the West Kiehl alkaline-surfactant-polymer field project and its application to mature Minnelusa waterfloods. Annual report for the period January 1993--December 1993
1994Co-Authors: M.j. Pitts, H. Surkalo, W.r. MundorfAbstract:The combination of an interfacial tension agent and a mobility control agent has the potential to produce additional Oil beyond a waterflood. The West Kiehl alkaline-surfactant-polymer project is the most advanced application of this chemical enhanced Oil recovery technique. The West Kiehl alkaline-surfactant-polymer flood was initiated in September 1987 as a secondary application after primary recovery. A preliminary analysis of the West Kiehl alkaline-surfactant-polymer flood indicates that incremental Oil of 20% of the original Stock Tank Oil in place will be produced above waterflooding. The cost of the incremental Oil will be less than $2.50 per incremental barrel. A statistical analysis of approximately 120 Minnelusa Oil fields in the Powder River Basin indicates that the original Stock Tank Oil in place exceeds one billion barrels. If the enhanced Oil recovery technology implemented at West Kiehl field could be successfully applied to these fields, the potential incremental Oil recovery would approach 200 million barrels. {open_quotes}Detailed Evaluation of the West Kiehl Alkaline-Surfactant-Polymer Field Project and Its Application to Mature Minnelusa Waterfloods{close_quotes} objective is to evaluate both the field performance of the alkaline-surfactant-polymer enhanced Oil recovery technology as well as its potential application to other Minnelusa Oil fields.
Jill S Buckley - One of the best experts on this subject based on the ideXlab platform.
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Verification of Asphaltene-Instability-Trend (ASIST) Predictions for Low-Molecular-Weight Alkanes
Spe Production & Operations, 2009Co-Authors: Jefferson L Creek, Jianxin Wang, Jill S BuckleyAbstract:Summary Anticipating when and where asphaltenes may flocculate during Oil production is a key step in successfully preventing or mitigating asphaltene problems in the field. Because there will be no deposition without precipitation, mapping of asphaltene stability over a wide range of temperature, pressure, and composition is required. The ASIST allows the determination of the onset of asphaltene instability to be established with a series of liquid n-alkanes. These data are used to predict asphaltene stability of live fluids by extrapolating the onset condition from the base data to reservoir conditions by use of a linear extrapolation of the onset solubility parameter vs. square root of the partial molar volume of the precipitant. This extrapolation has been demonstrated previously to be accurate for methane and a model Oil. The present work verifies that such an extrapolation is valid for predicting the asphaltene instability for mixtures of methane, ethane, and propane with a representative Stock-Tank Oil (STO). The STO was combined with known amounts of methane, ethane, or propane. The asphaltene onset pressure was determined by a combination of near-infrared (NIR) light scattering and microscopic observation. The onset conditions at ambient pressures were examined for flocculation periods ranging from 20 minutes to 24 hours. Onset pressures calculated with the 5-hour ASIST trends compared well with measured onset pressures.
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effect of dilution ratio on amount of asphaltenes separated from Stock Tank Oil
Journal of Dispersion Science and Technology, 2007Co-Authors: Jianxin Wang, Jill S BuckleyAbstract:We have investigated the effect of n‐alkane dilution on the amount of asphaltene separated from Stock ‐Tank Oil. Asphaltenes were produced from three different Oils by mixing each Oil with varying amounts of n‐alkanes, including n‐pentane, n‐hexane, and n‐heptane. The n‐alkane:Oil ratio ranged from 1∶1 to 1000∶1. With increasing n‐alkane:Oil ratio, the amount of separated asphaltene initially increased, passed through a maximum, then decreased gradually with further dilution. The maximum occurred at an n‐alkane:Oil ratio of around 30∶1 to 40∶1 for n‐hexane and n‐heptane, and 80∶1 for n‐pentane. A two‐component thermodynamic model based on Flory‐Huggins theory was adapted to match the observed trend of produced asphaltene by assuming a polydisperse model of the asphaltene fraction.
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asphaltene deposition on metallic surfaces
Journal of Dispersion Science and Technology, 2004Co-Authors: Jianxin Wang, Jill S Buckley, Jefferson L CreekAbstract:Abstract The potential for asphaltene deposition in wellbores and flowlines is a major concern during design of Oil production and transportation facilities, especially in deep‐water environments. Understanding the processes that control asphaltene deposition, especially the relationship between precipitation and deposition, can help to reduce the risk and cost. Stainless steel capillary tubes were used to study the influences of factors including temperature, degree of asphaltene instability, and precipitant molar volume on asphaltene deposition from mixtures of Stock‐Tank Oils and n‐alkanes. Temperature varied from 20°C to 60°C. Pressure drop across the capillary tube was used to estimate the amount and distribution of deposit formation. Existing asphaltic particles in Stock‐Tank Oil samples did not create deposits. Below the wax appearance temperature, intermittent pressure spikes indicated deposition of wax. Above the wax appearance temperature, deposition occurred gradually from near‐onset mixtures c...