# US 10,871,060 B2 · Hydraulic fracturing in kerogen-rich unconventional formations > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,871,060 B2 - Document ID: US10871060B2 - Status: Granted - Kind: B2 - Application number: 16/816,058 - Filed: 2020-03-11 - Published: 2020-07-02 - Granted: 2020-12-22 - Earliest claimed: 2016-06-23 - Assignees: Saudi Arabian Oil Company - Applicants: Saudi Arabian Oil Company - Inventors: Yanhui Han; Leiming Li; Ghaithan Muntasheri; Younane N. Abousleiman; Katherine Leigh Hull; David Jacobi - Web page: https://patentgrep.com/patent/US10871060B2 ## CPC - G06F 30/28: using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD] - C09K 8/62: Compositions for forming crevices or fractures - E21B 41/00: Equipment or details not covered by groups E21B15/00 - E21B40/00 - E21B 43/24: using heat, e.g. steam injection - E21B 43/26: by forming crevices or fractures - E21B 43/267: reinforcing fractures by propping - G01V 20/00: Geomodelling in general - G06F 30/20: Design optimisation, verification or simulation (optimisation, verification or simulation of circuit designs G06F30/30) - G06Q 30/0201: Market modelling; Market analysis; Collecting market data - E21B 49/00: Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells - G06F: ELECTRIC DIGITAL DATA PROCESSING (computer systems based on specific computational models G06N) - C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - G01V: GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS (means for indicating the location of accidentally buried, e.g. snow-buried, persons A63B29/02) - G06Q: INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR ## Abstract The subject matter of this specification can be embodied in, among other things, a method for treating a geologic formation that includes providing a hydraulic fracture model, providing a first value representative of a volume of kerogen breaker in a fracturing fluid, determining a discrete fracture network (DFN) based on the hydraulic fracture model and the first value, determining a geomechanical model based on the DFN and a reservoir model based on the DFN, determining a hydrocarbon production volume based on the geomechanical model and the reservoir model, adjusting the first value based on the hydrocarbon production volume, and adjusting a volume of kerogen breaker in the fracturing fluid to a hydrocarbon reservoir based on the adjusted first value. ## Claims ### Claim 1 A method for treating a geologic formation, comprising: receiving a hydraulic fracture model configured to simulate a main hydraulic fracturing stimulation; receiving a first value representative of a volume of kerogen breaker in a fracturing fluid; determining a discrete fracture network (DFN) comprising: a description of a number of fractures, wherein each fracture is characterized by one or more of length, width, height, and orientation that are estimated based on the hydraulic fracture model; and predicted effects of the volume of kerogen breaker represented by the first value on initiation and propagation of the fractures and sustainability of the fractures during hydrocarbon extraction; determining a first hydrocarbon production volume value based on a geomechanical model and the DFN; determining a second hydrocarbon production volume value based on a reservoir model and the DFN; determining a third estimated hydrocarbon production volume based on the determined first hydrocarbon production volume value and the determined second hydrocarbon production volume value; adjusting the first value based on the determined third estimated hydrocarbon production volume value; adjusting a volume of kerogen breaker in the fracturing fluid based on the adjusted first value; providing the adjusted volume of kerogen breaker in the fracturing fluid to a hydrocarbon reservoir in a subterranean zone; modifying shale stiffness and strength properties in the hydrocarbon reservoir based on the adjusted volume of kerogen breaker; and extracting a volume of hydrocarbon from the hydrocarbon reservoir based on the modified shale stiffness and strength properties in the hydrocarbon reservoir, wherein the third estimated hydrocarbon production volume is predictive of the extracted volume. ### Claim 2 (depends on 1) The method of claim 1, further comprising: providing a second value representative of an amount of heat to apply to the hydrocarbon reservoir in the subterranean zone; adjusting the second value based on the third estimated hydrocarbon production volume value; wherein, determining the DFN is further based on the second value; and adjusting the amount of heat to apply to the hydrocarbon reservoir in the subterranean zone is further based on the second value. ### Claim 3 (depends on 2) The method of claim 2, wherein the amount of heat has a heating cost, the third estimated hydrocarbon production volume has a market value, and adjusting the second value comprises determining a difference between the market value and the heating cost and adjusting the second value to increase the difference. ### Claim 4 (depends on 2) The method of claim 2, further comprising adjusting the second value based on the extracted volume, wherein the extracted volume is based on the volume of kerogen breaker in the fracturing fluid. ### Claim 5 (depends on 1) The method of claim 1, wherein the volume of kerogen breaker in the fracturing fluid has a material cost, the estimated third hydrocarbon production volume has a market value, and adjusting the first value comprises determining a difference between the market value and the material cost and adjusting the first value to increase the difference. ### Claim 6 (depends on 1) The method of claim 1, wherein the DFN is descriptive of one or more of new fractures that are predicted to be created based on the hydraulic fracture model, modified shale properties predicted to be modified based on the hydraulic fracture model, and reactivated fractures that are predicted to be reactivated based on the hydraulic fracture model and the modified shale properties. ### Claim 7 (depends on 1) The method of claim 1, wherein the hydraulic fracture model is configured to determine the DFN further based on one or more of in-situ stresses in the hydrocarbon reservoir, pore pressures in the hydrocarbon reservoir, injection plans of a fracturing job, heterogeneity in the hydrocarbon reservoir, elastic stiffness properties of reservoir rocks, plastic strength properties of reservoir rocks, and mechanical properties of heterogeneities, and the DFN comprises a number of fractures each characterized by one or more of fracture length, fracture width, fracture height, and fracture orientation. ### Claim 8 (depends on 1) The method of claim 1, wherein the geomechanical model is configured to predict evolution of at least one of stress fields, deformation, and damage in the hydrocarbon reservoir based on one or more of in-situ stresses in the hydrocarbon reservoir, pore pressures in the hydrocarbon reservoir, rock masses of reservoir layers, the DFN, constitutive models of rock mass that describe stress-deformation-failure processes of reservoirs under loading modes, mechanical properties of rock masses, mechanical properties of fractures, fluid mechanical interaction parameters, and thermal mechanical coupling parameters. ### Claim 9 (depends on 1) The method of claim 1, wherein the reservoir model is configured to predict evolution of multiphase flow and pressure fields in the hydrocarbon reservoir based on one or more of reservoir pressure distribution parameters, reservoir temperature distribution parameters, multiphase flow models for fluid flow in rock, multiphase flow models for fluid flow in the DFN, thermal conduction models, thermal convection models, porosity parameters, permeability parameters, saturation parameters, thermal conduction property parameters, thermal convection property parameters, well location parameters, well drawdown plan parameters, and well temperature parameters. ### Claim 10 (depends on 1) The method of claim 1, further comprising adjusting the first value based on the extracted volume, wherein the extracted volume is based on the volume of kerogen breaker in the fracturing fluid. ### Claim 11 A system for hydraulic fracturing comprising: a control system comprising one or more processors; and a non-transitory computer-readable medium storing instructions executable by the one or more processors to perform operations comprising: receive a first value representative of a volume of kerogen breaker in a fracturing fluid; determining a discrete fracture network (DFN) comprising: a description of a number of fractures, wherein each fracture is characterized by one or more of length, width, height, and orientation that are estimated based on a hydraulic fracture model; and predicted effects of the volume of kerogen breaker represented by the first value on initiation and propagation of the fractures and sustainability of the fractures during hydrocarbon extraction; determining a first hydrocarbon production volume value, by a geomechanical model based on the DFN; determining a second hydrocarbon production volume value, by a reservoir model based on the DFN; determining an third estimated hydrocarbon production volume based on the determined first hydrocarbon production volume value and the determined second hydrocarbon production volume value; adjusting, by an adjustment module, the first value based on the determined third estimated hydrocarbon production volume; controlling, by the control system, a valve to adjust a volume of kerogen breaker in the fracturing fluid based on the adjusted first value; and providing, based on the controlling, the adjusted volume of kerogen breaker in the fracturing fluid to a hydrocarbon reservoir in a subterranean zone, wherein shale stiffness and strength properties in the hydrocarbon reservoir are modified based on the adjusted volume of kerogen breaker such that the third estimated hydrocarbon production volume is predictive of a volume of hydrocarbon extracted from the hydrocarbon reservoir based on the modified shale stiffness and strength properties in the hydrocarbon reservoir. ### Claim 12 (depends on 11) The system of claim 11, wherein: the hydraulic fracture model is configured to determine the discrete fracture network (DFN) further based on a second value representative of an amount of heat to apply to the hydrocarbon reservoir; and the adjustment module is further configured to adjust the second value based on the third estimated hydrocarbon production volume. ### Claim 13 (depends on 12) The system of claim 12, wherein the amount of heat has a heating cost, the third estimated hydrocarbon production volume has a market value, and the adjustment module is further configured to adjust the second value based on determining a difference between the market value and the heating cost and adjusting the second value to increase the difference. ### Claim 14 (depends on 12) The system of claim 12, further comprising a valve configured to adjust delivery of heat provided to a hydrocarbon reservoir based on the adjusted second value. ### Claim 15 (depends on 11) The system of claim 11, wherein the volume of kerogen breaker in the fracturing fluid has a material cost, the third estimated hydrocarbon production volume has a market value, and the adjustment module is further configured to adjust the second value based on determining a difference between the market value and the material cost and adjusting the first value to increase the difference. ### Claim 16 (depends on 11) The system of claim 11, wherein the DFN is descriptive of one or more of new fractures that are predicted to be created based on the hydraulic fracture model, modified shale properties predicted to be modified based on the hydraulic fracture model, and reactivated fractures that are predicted to be reactivated based on the hydraulic fracture model and the modified shale properties. ### Claim 17 (depends on 11) The system of claim 11, wherein the hydraulic fracture model is configured to determine the DFN further based on one or more of in-situ stresses in the hydrocarbon reservoir, pore pressures in the hydrocarbon reservoir, injection plans of a fracturing job, heterogeneity in the hydrocarbon reservoir, elastic stiffness properties of reservoir rocks, plastic strength properties of reservoir rocks, and mechanical properties of heterogeneities, and the DFN comprises a number of fractures each characterized by one or more of fracture length, fracture width, fracture height, and fracture orientation. ### Claim 18 (depends on 11) The system of claim 11, wherein the geomechanical model is configured to predict evolution of at least one of stress fields, deformation, and damage in the hydrocarbon reservoir based on one or more of in-situ stresses in the hydrocarbon reservoir, pore pressures in the hydrocarbon reservoir, rock masses of reservoir layers, the DFN, constitutive models of rock mass that describe stress-deformation-failure processes of reservoirs under loading modes, mechanical properties of rock masses, mechanical properties of fractures, fluid mechanical interaction parameters, and thermal mechanical coupling parameters. ### Claim 19 (depends on 11) The system of claim 11, wherein the reservoir model is configured to predict evolution of multiphase flow and pressure fields in the hydrocarbon reservoir based on one or more of reservoir pressure distribution parameters, reservoir temperature distribution parameters, multiphase flow models for fluid flow in rock, multiphase flow models for fluid flow in the DFN, thermal conduction models, thermal convection models, porosity parameters, permeability parameters, saturation parameters, thermal conduction property parameters, thermal convection property parameters, well location parameters, well drawdown plan parameters, and well temperature parameters.