Patents by Inventor Ian Ralph Collins
Ian Ralph Collins 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).
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Publication number: 20230358694Abstract: A method of assessing the response of a reservoir rock to low salinity water includes obtaining a formation core sample of a reservoir rock from a reservoir. In addition, the method includes sequentially washing the formation core sample with a first series of solvents to form a first series of solvent extracts and an extracted formation core sample. Further, the method includes sequentially washing the extracted formation core sample with a second series of solvents to form a second series of solvent extracts and a cleaned formation core sample. The method also includes generating a series of mass spectra of the second series of solvent extracts. The relative abundance of the catecholamine-type structures (CTS) is determined using the series of mass spectra. Still further, the method includes subjecting the formation core sample to analysis by X-ray diffraction to generate a diffraction pattern. The relative abundance of kalonite is determined using the diffraction pattern.Type: ApplicationFiled: December 1, 2021Publication date: November 9, 2023Applicant: BP CORPORATION NORTH AMERICA INC.Inventors: Huang Zeng, Christianne Clare Wicking, Nathalia Tessarolo, John William Couves, Ian Ralph Collins
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Patent number: 11648511Abstract: A method includes producing a first blended low salinity injection water for injection into at least one injection well that penetrates a first region of an oil-bearing reservoir and producing a second blended low salinity injection water for injection into at least one injection well that penetrates a second region of an oil-bearing reservoir. The reservoir rock of the first and second regions has first and second rock compositions, respectively, that present different risks of formation damage. The first and second blended low salinity injection waters comprise variable amounts of nanofiltration permeate and reverse osmosis permeate.Type: GrantFiled: September 12, 2018Date of Patent: May 16, 2023Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, John William Couves, John Henry Crouch, John Dale Williams
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Patent number: 11162311Abstract: An integrated system includes a desalination plant including a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream. The integrated system also includes a blending system. a control unit, and an injection system for an injection well that penetrates an oil-bearing layer of a reservoir. The blending system is to blend the RO permeate blending stream and the NF permeate blending stream to produce a blended injection water stream. The control unit is to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to alter the composition of the blended injection water stream from an initial composition to a target composition.Type: GrantFiled: August 9, 2018Date of Patent: November 2, 2021Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, John William Couves, John Henry Crouch, John Dale Williams
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Patent number: 10913891Abstract: A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200° C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).Type: GrantFiled: January 2, 2019Date of Patent: February 9, 2021Assignee: BP CORPORATION NORTH AMERICA INC.Inventors: James Neil, Spencer Taylor, Huang Zeng, Allan Peats, Giovanna Boccardo, John V. Bullen, Ian Ralph Collins, Andrew Rees
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Patent number: 10815777Abstract: A method for detecting incremental oil production from an oil-bearing reservoir includes taking a baseline sample of the oil and analyzing the baseline sample of oil to establish a baseline compositional signature for the oxygen-containing organic compounds in the oil. In addition, the method includes commencing a low salinity waterflood by injecting a low salinity water into the reservoir from an injection well. Further, the method includes recovering oil from a production well. Still further, the method includes taking post-flood samples of the oil produced from the production well over time. The method also includes analyzing the post-flood samples of oil to establish post-flood compositional signatures for the oxygen-containing organic compounds in the oil. Moreover, the method includes identifying a difference between one or more of the post-flood compositional signatures and the baseline compositional signature that is characteristic of incremental oil released by the low salinity waterflood.Type: GrantFiled: March 14, 2017Date of Patent: October 27, 2020Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, John William Couves, Michael Graham Hodges, Christian Schack Pedersen, Peter Anthony Salino, Christianne Clare Wicking
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Publication number: 20200248514Abstract: An integrated system includes a desalination plant including a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream. The integrated system also includes a blending system, a control unit, and an injection system for an injection well that penetrates an oil-bearing layer of a reservoir. The blending system is to blend the RO permeate blending stream and the NF permeate blending stream to produce a blended injection water stream. The control unit is to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to alter the composition of the blended injection water stream from an initial composition to a target composition.Type: ApplicationFiled: August 9, 2018Publication date: August 6, 2020Applicant: BP Exploration Operating Company LimitedInventors: Ian Ralph Collins, John William Couves, John Henry Crouch, John Dale Williams
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Publication number: 20200230554Abstract: A method includes producing a first blended low salinity injection water for injection into at least one injection well that penetrates a first region of an oil-bearing reservoir and producing a second blended low salinity injection water for injection into at least one injection well that penetrates a second region of an oil-bearing reservoir. The reservoir rock of the first and second regions has first and second rock compositions, respectively, that present different risks of formation damage. The first and second blended low salinity injection waters comprise variable amounts of nanofiltration permeate and reverse osmosis permeate.Type: ApplicationFiled: September 12, 2018Publication date: July 23, 2020Applicant: BP Exploration Operating Company LimitedInventors: Ian Ralph Collins, John William Couves, John Henry Crouch, John Dale Williams
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Publication number: 20190136124Abstract: A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200° C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).Type: ApplicationFiled: January 2, 2019Publication date: May 9, 2019Applicant: BP Corporation North America Inc.Inventors: James Neil, Spencer Taylor, Huang Zeng, Allan Peats, Giovanna Boccardo, John V. Bullen, Ian Ralph Collins, Andrew Rees
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Publication number: 20190100996Abstract: A method for detecting incremental oil production from an oil-bearing reservoir includes taking a baseline sample of the oil and analyzing the baseline sample of oil to establish a baseline compositional signature for the oxygen-containing organic compounds in the oil. In addition, the method includes commencing a low salinity waterflood by injecting a low salinity water into the reservoir from an injection well. Further, the method includes recovering oil from a production well. Still further, the method includes taking post-flood samples of the oil produced from the production well over time. The method also includes analyzing the post-flood samples of oil to establish post-flood compositional signatures for the oxygen-containing organic compounds in the oil. Moreover, the method includes identifying a difference between one or more of the post-flood compositional signatures and the baseline compositional signature that is characteristic of incremental oil released by the low salinity waterflood.Type: ApplicationFiled: March 14, 2017Publication date: April 4, 2019Inventors: Ian Ralph Collins, John William Couves, Michael Graham Hodges, Christian Schack Pedersen, Peter Anthony Salino, Christianne Clare Wicking
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Patent number: 10227858Abstract: A computer-implemented method for determining one or more operating modes for a crude oil displacement system is provided. The crude oil displacement system is arranged to inject an aqueous displacement fluid into one or more reservoirs, each reservoir comprising a porous and permeable rock formation, wherein crude oil and formation water are contained within a pore space of the rock formation. The crude oil displacement system is for use in displacing crude oil from the pore space of the rock formation. The computer-implemented method comprises the steps of receiving measurement data associated with one or more chemical characteristics of the displacement fluid and one or more chemical characteristics of the rock formation, the crude oil and the formation water of the one or more reservoirs, and inputting the measurement data and data representing a predetermined volume of oil into a computer-implemented predictive model.Type: GrantFiled: July 2, 2015Date of Patent: March 12, 2019Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, Stephanie Jane Houston, Kevin John Webb
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Patent number: 10214683Abstract: A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200 C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).Type: GrantFiled: January 12, 2016Date of Patent: February 26, 2019Assignee: BP Corporation North America IncInventors: James Neil, Spencer Taylor, Huang Zeng, Allan Peats, Giovanna Boccardo, John V. Bullen, Ian Ralph Collins, Andrew Rees
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Publication number: 20180163523Abstract: A method for recovering crude oil from a reservoir that is penetrated by at least one injection well includes injecting an aqueous displacement fluid into the reservoir from the injection well. The displacement fluid includes a solution of a zinc salt in an aqueous base fluid. The aqueous base fluid has a total dissolved solids (TDS) concentration in the range of 200 to 250,000 ppmv (parts per million based on the volume of the aqueous base fluid) and a viscosity in the range of 1.00 to 2.00 centipoise (cP) at standard temperature and pressure. The aqueous displacement fluid has a dissolved zinc concentration in the range of 10 to 3,750 ppmv. The aqueous displacement fluid includes dissolved chloride. The molar ratio of dissolved chloride to dissolved zinc in the aqueous displacement fluid is at least 5:1.Type: ApplicationFiled: February 7, 2018Publication date: June 14, 2018Applicant: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, Arnaud Lager
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Patent number: 9982520Abstract: A method for recovering crude oil from a reservoir that is penetrated by at least one injection well, the method comprising: injecting an aqueous displacement fluid comprising a solution of a zinc salt in an aqueous base fluid into the reservoir from the injection well wherein the aqueous base fluid has a total dissolved solids (TDS) concentration in the range of 200 to 250,000 ppmv (parts per million based on the volume of the aqueous base fluid), and a viscosity in the range of 1.00 to 2.00 centipoise (cP) at standard temperature and pressure; and wherein the aqueous displacement fluid has a dissolved zinc concentration in the range of 10 to 3,750 ppmv.Type: GrantFiled: July 15, 2014Date of Patent: May 29, 2018Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, Arnaud Lager
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Publication number: 20180002595Abstract: A method for producing hydrocarbons within a reservoir includes (a) injecting an aqueous solution into the reservoir. The aqueous solution includes water and a thermally activated chemical species. The thermally activated chemical species is urea, a urea derivative, or a carbamate. The thermally activated chemical agent is thermally activated at or above a threshold temperature less than 200 C. In addition, the method includes (b) thermally activating the thermally activated chemical species in the aqueous solution during or after (a) at a temperature equal to or greater than the threshold temperature to produce carbon-dioxide and at least one of ammonia, amine, and alkanolamine within the reservoir. Further, the method includes (c) increasing the water wettability of the subterranean formation in response to the thermally activation in (b). Still further, the method includes (d) waterflooding the reservoir with water after (a), (b) and (c).Type: ApplicationFiled: January 12, 2016Publication date: January 4, 2018Applicant: BP Corporation North America Inc.Inventors: James Neil, Spencer Taylor, Huang Zeng, Allan Peats, Giovanna Boccardo, John V. Bullen, Ian Ralph Collins, Andrew Rees
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Patent number: 9804062Abstract: The invention relates to an apparatus for simultaneously injecting fluids into a plurality of samples of porous media, comprising: a plurality of holders for the samples of porous media, each holder comprising a sleeve and first and second platens, the first platen having an inlet for an injection fluid and the second platen having an outlet for a produced fluid, and the samples of porous media being arranged, in use, in each of the holders such that the first platen and second platen of each holder contact a first and second end of the sample of porous medium respectively, the inlet of each first platen being in fluid communication with an injection line for injecting fluid into the sample of porous medium arranged in the holder, the outlet of each second platen being in fluid communication with a dedicated effluent line for removing fluid produced from the sample of porous medium arranged in the holder, on-line and/or off-line analytical means for analyzing the fluids injected into each of the samples of poType: GrantFiled: December 22, 2015Date of Patent: October 31, 2017Inventors: Ian Ralph Collins, John William Couves, Bogdan Costin Gagea, Arnaud Lager, Kevin John Webb
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Patent number: 9575203Abstract: method of comparing a secondary oil recovery process with a tertiary oil recovery process, the secondary oil recovery process and the tertiary oil recovery process being applied to a substantially fluid-saturated porous medium containing an oil phase and an aqueous phase. The method comprising using relaxation time measurements in the calculation of a wettability index modification factor for the oil phase or the aqueous phase, thereby comparing the tertiary oil recovery process with the secondary oil recovery process.Type: GrantFiled: November 19, 2010Date of Patent: February 21, 2017Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Quan Chen, Ian Ralph Collins
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Publication number: 20160160621Abstract: A method for recovering crude oil from a reservoir that is penetrated by at least one injection well, the method comprising: injecting an aqueous displacement fluid comprising a solution of a zinc salt in an aqueous base fluid into the reservoir from the injection well wherein the aqueous base fluid has a total dissolved solids (TDS) concentration in the range of 200 to 250,000 ppmv (parts per million based on the volume of the aqueous base fluid), and a viscosity in the range of 1.00 to 2.00 centipoise (cP) at standard temperature and pressure; and wherein the aqueous displacement fluid has a dissolved zinc concentration in the range of 10 to 3,750 ppmv.Type: ApplicationFiled: July 15, 2014Publication date: June 9, 2016Inventors: Ian Ralph COLLINS, Arnaud LAGER
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Publication number: 20160109334Abstract: The invention relates to an apparatus for simultaneously injecting fluids into a plurality of samples of porous media, comprising: a plurality of holders for the samples of porous media, each holder comprising a sleeve and first and second platens, the first platen having an inlet for an injection fluid and the second platen having an outlet for a produced fluid, and the samples of porous media being arranged, in use, in each of the holders such that the first platen and second platen of each holder contact a first and second end of the sample of porous medium respectively, the inlet of each first platen being in fluid communication with an injection line for injecting fluid into the sample of porous medium arranged in the holder, the outlet of each second platen being in fluid communication with a dedicated effluent line for removing fluid produced from the sample of porous medium arranged in the holder, on-line and/or off-line analytical means for analyzing the fluids injected into each of the samples of poType: ApplicationFiled: December 22, 2015Publication date: April 21, 2016Inventors: Ian Ralph Collins, John William Couves, Bogdan Costin Gagea, Arnaud Lager, Kevin John Webb
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Patent number: 9261435Abstract: The invention relates to an apparatus for simultaneously injecting fluids into a plurality of samples of porous media, comprising: a plurality of holders for the samples of porous media, each holder comprising a sleeve and first and second platens, the first platen having an inlet for an injection fluid and the second platen having an outlet for a produced fluid, and the samples of porous media being arranged, in use, in each of the holders such that the first platen and second platen of each holder contact a first and second end of the sample of porous medium respectively, the inlet of each first platen being in fluid communication with an injection line for injecting fluid into the sample of porous medium arranged in the holder, the outlet of each second platen being in fluid communication with a dedicated effluent line for removing fluid produced from the sample of porous medium arranged in the holder, on-line and/or off-line analytical means for analyzing the fluids injected into each of the samples of poType: GrantFiled: July 29, 2011Date of Patent: February 16, 2016Assignee: BP EXPLORATION OPERATING COMPANY LIMITEDInventors: Ian Ralph Collins, John William Couves, Bogdan Costin Gagea, Arnaud Lager, Kevin John Webb
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Publication number: 20150300149Abstract: A computer-implemented method for determining one or more operating modes for a crude oil displacement system is provided. The crude oil displacement system is arranged to inject an aqueous displacement fluid into one or more reservoirs, each reservoir comprising a porous and permeable rock formation, wherein crude oil and formation water are contained within a pore space of the rock formation. The crude oil displacement system is for use in displacing crude oil from the pore space of the rock formation. The computer-implemented method comprises the steps of receiving measurement data associated with one or more chemical characteristics of the displacement fluid and one or more chemical characteristics of the rock formation, the crude oil and the formation water of the one or more reservoirs, and inputting the measurement data and data representing a predetermined volume of oil into a computer-implemented predictive model.Type: ApplicationFiled: July 2, 2015Publication date: October 22, 2015Inventors: Ian Ralph Collins, Stephanie Jane HOUSTON, Kevin John WEBB