Patents by Inventor James J. Sheng
James J. Sheng has filed for patents to protect the following inventions. This listing includes patent applications that are pending as well as patents that have already been granted by the United States Patent and Trademark Office (USPTO).
-
Publication number: 20230349278Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: ApplicationFiled: May 15, 2023Publication date: November 2, 2023Applicant: TEXAS TECH UNIVERSITY SYSTEMInventor: James J. Sheng
-
Patent number: 11725492Abstract: A method for generating microfractures in low carbonate mineral content shale reservoirs in which sulfate acid or persulfate compound (such as ammonium persulfate ((NH4)2S2O8)) injected into conventional fracturing fluid can react with shale carbonate components resulting in the precipitation reaction of gypsum crystal (CaSO4ยท2H2O) to occur.Type: GrantFiled: June 7, 2019Date of Patent: August 15, 2023Assignee: Texas Tech University SystemInventors: Qiang Chen, James J. Sheng
-
Patent number: 11649707Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: GrantFiled: April 2, 2021Date of Patent: May 16, 2023Assignee: Texas Tech University SystemInventor: James J. Sheng
-
Publication number: 20210222532Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: ApplicationFiled: April 2, 2021Publication date: July 22, 2021Applicant: Texas Tech University SystemInventor: James J. Sheng
-
Patent number: 11008840Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: GrantFiled: November 25, 2019Date of Patent: May 18, 2021Assignee: Texas Tech University SystemInventor: James J. Sheng
-
Publication number: 20200088016Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: ApplicationFiled: November 25, 2019Publication date: March 19, 2020Applicant: Texas Tech University SystemInventor: James J. Sheng
-
Publication number: 20190376376Abstract: Method to generate microfractures by chemical reaction in low carbonate mineral content shale reservoirs in which sulfate acid or persulfate compound (such as ammonium persulfate ((NH4)2S2O8) at a relatively high content) injected into conventional fracturing fluid can react with shale carbonate components resulting in the precipitation reaction of gypsum crystal (CaSO4.2H2O) to occur because an insoluble calcium sulfate (CaSO4) solid is formed. It has been found that expansion stress generated by rapid crystallization in the shale nanoscale pore space can intensively crack shale rocks without additional energy input. Not only does this lead to the formation of much denser secondary microfracture networks, it also can increase SRV by the micrometer-scale gypsum crystals prohibiting these secondary microfracture networks from closure under a normal stress, thereby, improve the efficiency of hydraulic fracturing and hydrocarbon production.Type: ApplicationFiled: June 7, 2019Publication date: December 12, 2019Applicant: TEXAS TECH UNIVERSITY SYSTEMInventors: Qiang Chen, James J. Sheng
-
Patent number: 10487635Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: GrantFiled: December 7, 2016Date of Patent: November 26, 2019Assignee: TEXAS TECH UNIVERSITY SYSTEMInventor: James J. Sheng
-
Patent number: 9932808Abstract: A process of producing liquid oil from shale gas condensate reservoirs and, more particularly, to increase liquid oil production by huff-n-puff in shale gas condensate reservoirs. The process includes performing a huff-n-puff gas injection mode and flowing the bottom-hole pressure lower than the dew point pressure.Type: GrantFiled: June 11, 2015Date of Patent: April 3, 2018Assignee: Texas Tech University SystemInventor: James J. Sheng
-
Publication number: 20170159416Abstract: Methods for optimization of liquid oil production by huff-n-puff in shale reservoirs to achieve an improved (and optimal) oil recovery factor. The process determines and utilizes the optimum huff and puff times, number of cycles and soaking time under practical operation and reservoir conditions. The huff time in the process is a period so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period. The puff time in the process is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. Soaking is typically not necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determinable by the time in which the economic rate cut-off is reached.Type: ApplicationFiled: December 7, 2016Publication date: June 8, 2017Applicant: Texas Tech University SystemInventor: James J. Sheng
-
Publication number: 20170122086Abstract: A process of producing liquid oil from shale gas condensate reservoirs and, more particularly, to increase liquid oil production by huff-n-puff in shale gas condensate reservoirs. The process includes performing a huff-n-puff gas injection mode and flowing the bottom-hole pressure lower than the dew point pressure.Type: ApplicationFiled: June 11, 2015Publication date: May 4, 2017Applicant: TEXAS TECH UNIVERSITY SYSTEMInventor: James J. Sheng
-
Publication number: 20090194276Abstract: Systems and methods for the determination of an optimum salinity type and an optimum salinity of a surfactant microemulsion system are shown. Optimum salinity type and optimum salinity in surfactant/polymer flooding is determined, according to embodiments, by core-flood experiments so that a variety of multiphase flow parameters such as relative permeability and phase trapping that affects oil recovery factor, influences the determination of the optimum salinity type and optimum salinity. The optimum salinity determined from this approach preferably corresponds to the highest oil recovery factor.Type: ApplicationFiled: January 31, 2008Publication date: August 6, 2009Applicant: Total E&P USA, Inc.Inventor: James J. Sheng
-
Publication number: 20090194281Abstract: An optimum salinity profile in surfactant/polymer flooding from formation water to post-flush drive that leads to the highest oil recovery factor is shown. The optimum salinity determined from core-flooding experiments is preferably used in the surfactant slug. The surfactant slug is protected from deterioration by the injection of cushion slugs immediately before and after the injection of the surfactant slug in a reservoir wherein the cushion slugs have the same salinity or about the same salinity as the surfactant slug. According to embodiments, a salinity lower than the lowest salinity of Type III, Csel, is used in the post-flush drive, while formation water could be of any salinity.Type: ApplicationFiled: January 31, 2008Publication date: August 6, 2009Applicant: Total E&P USA, Inc.Inventor: James J. Sheng
-
Patent number: 7448263Abstract: In one method, the permeabilities are obtained by correcting the geometric factor derived from combining the FRA analysis and buildup analysis.Type: GrantFiled: January 22, 2007Date of Patent: November 11, 2008Assignee: Baker Hughes IncorporatedInventors: James J. Sheng, Daniel T. Georgi
-
Patent number: 7448262Abstract: In one method, the permeabilities are obtained by correcting the geometric factor derived from combining the FRA analysis and buildup analysis. In a second method, the permeabilities are obtained by combining the spherical permeability estimated from buildup analysis and the geometric skin factor obtained from history matching the probe-pressure data. In other methods, horizontal and vertical permeabilities are determined by analysis of pressure drawdown made with a single probe of circular aperture in a deviated borehole at two different walls of the borehole.Type: GrantFiled: August 12, 2005Date of Patent: November 11, 2008Assignee: Baker Hughes IncorporatedInventors: James J. Sheng, Daniel T. Georgi
-
Patent number: 7231818Abstract: In one method, the permeabilities are obtained by correcting the geometric factor derived from combining the FRA analysis and buildup analysis. In a second method, the permeabilities are obtained by combining the spherical permeability estimated from buildup analysis and the geometric skin factor obtained from history matching the probe-pressure data. In another method, horizontal and vertical permeabilities are determined by analysis of pressure drawdown made with a single probe of circular aperture in a substantially horizontal borehole at two different walls of the borehole.Type: GrantFiled: December 16, 2004Date of Patent: June 19, 2007Assignee: Baker Hughes IncorporatedInventors: James J. Sheng, Daniel T. Georgi
-
Patent number: 7181960Abstract: In one method, the permeabilities are obtained by correcting the geometric factor derived from combining the FRA analysis and buildup analysis. In a second method, the permeabilities are obtained by combining the spherical permeability estimated from buildup analysis and the geometric skin factor obtained from history matching the probe-pressure data. In other methods, horizontal and vertical permeabilities are determined by analysis of pressure drawdown made with a single probe of circular aperture in a deviated borehole at two different walls of the borehole.Type: GrantFiled: August 12, 2005Date of Patent: February 27, 2007Assignee: Baker Hughes IncorporatedInventors: James J. Sheng, Daniel T. Georgi