# US 10,246,980 B2 · Flooding process for hydrocarbon recovery from a subsurface formation > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,246,980 B2 - Document ID: US10246980B2 - Status: Granted - Kind: B2 - Application number: 15/273,893 - Filed: 2016-09-23 - Published: 2018-03-29 - Granted: 2019-04-02 - Earliest claimed: 2016-09-23 - Assignees: Statoil Gulf Services LLC - Applicants: Statoil Gulf Services LLC - Inventors: Huina Li - Web page: https://patentgrep.com/patent/US10246980B2 ## CPC - E21B 43/2605: {using gas or liquefied gas} - E21B 43/14: Obtaining from a multiple-zone well - E21B 43/164: {Injecting CO2 or carbonated water (in combination with organic material C09K8/594)} - E21B 43/168: {Injecting a gaseous medium} - E21B 43/17: Interconnecting two or more wells by fracturing or otherwise attacking the formation ({E21B43/2405,} E21B43/247 take precedence) - E21B 43/20: Displacing by water - E21B 43/305: {comprising at least one inclined or horizontal well} - E21B 43/267: reinforcing fractures by propping - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract A method of treating a subsurface formation with low permeability to increase total oil production from the formation is disclosed. The method may include providing a first fluid into two or more fractures emanating from a first wellbore. The first fluid may be provided at a pressure below a fracture pressure of the formation. The first fluid may increase a pressure in zones substantially surrounding a first fracture and a second fracture emanating from the first wellbore. A zone having a lower pressure may be located between these zones. Additional fractures may be formed from a second wellbore in the formation with at least one of the additional fractures emanating from the second wellbore and propagating into the lower pressure zone. Hydrocarbons may be produced from the second wellbore. A second fluid may be provided into the first wellbore before and/or after producing the hydrocarbons from the second wellbore. ## Claims ### Claim 1 A method of treating a subsurface formation, comprising: providing a first fluid into two or more fractures emanating from a first wellbore in the formation, wherein at least some hydrocarbons have been produced from the formation through the fractures and the first wellbore, and wherein a majority of the first fluid is provided at a pressure below a fracture pressure of the subsurface formation; wherein the first fluid increases a pressure in a first zone of the formation substantially surrounding at least a first fracture emanating from the first wellbore, and wherein the first fluid increases a pressure in a second zone of the formation substantially surrounding at least a second fracture emanating from the first wellbore; wherein a third zone of the formation is located at least partially between the first zone and the second zone, and wherein the third zone has a pressure below both the pressure in the first zone and the pressure in the second zone after the first fluid increases the pressures in the first zone and the second zone; forming one or more additional fractures from a second wellbore in the formation, wherein the second wellbore is substantially parallel to the first wellbore, and wherein at least one of the additional fractures emanates from the second wellbore and propagates into the third zone of the formation; producing at least some hydrocarbons from the second wellbore; and following said step of forming one or more additional fractures from the second wellbore in the formation, providing a second fluid into the first wellbore. ### Claim 2 (depends on 1) The method of claim 1, wherein at least one of the fractures emanating from the first wellbore comprises a fracture formed from the first wellbore prior to providing the first fluid into the first wellbore. ### Claim 3 (depends on 1) The method of claim 1, wherein the first wellbore comprises a substantially horizontal wellbore in the formation. ### Claim 4 (depends on 1) The method of claim 1, wherein the increased pressure in the first zone is at least about 1000 psi greater than the pressure in the third zone. ### Claim 5 (depends on 1) The method of claim 1, wherein the increased pressure in the second zone is at least about 1000 psi greater than the pressure in the third zone. ### Claim 6 (depends on 1) The method of claim 1, wherein the first wellbore is positioned in a portion of the subsurface formation with an average matrix permeability of at most about 1 mD. ### Claim 7 (depends on 1) The method of claim 1, wherein the first fluid comprises at least about 95% by weight water. ### Claim 8 (depends on 1) The method of claim 1, wherein the first fluid comprises carbon dioxide, natural gas, or a combination thereof. ### Claim 9 (depends on 1) The method of claim 1, wherein the second fluid comprises at least about 95% by weight water. ### Claim 10 (depends on 9) The method of claim 9, wherein the second fluid further comprises anionic surfactant, cationic surfactant, zwitterionic surfactant, non-ionic surfactant, or combinations thereof. ### Claim 11 (depends on 1) The method of claim 1, wherein the second fluid comprises carbon dioxide, natural gas, or a combination thereof. ### Claim 12 (depends on 1) The method of claim 1, wherein the additional fracture that propagates into the third zone is inhibited from intersecting with the fractures emanating from the first wellbore. ### Claim 13 (depends on 1) The method of claim 1, further comprising providing the first fluid into the first wellbore at an injection rate of at most about 50 bbl/min. ### Claim 14 (depends on 1) The method of claim 1, wherein the one or more additional fractures from the second wellbore are formed by stimulating the wellbore with fracturing fluids. ### Claim 15 A method of treating a subsurface formation, comprising: forming a plurality of fractures from a first wellbore in the formation, the plurality of fractures emanating from the first wellbore and propagating into the formation; producing at least some hydrocarbons from the first wellbore; providing a first fluid into two or more of the fractures emanating from the first wellbore, wherein a majority of the first fluid is provided at a pressure below a fracture pressure of the subsurface formation; wherein the first fluid increases a minimum horizontal stress of the formation in a first volume of the formation substantially surrounding at least a first fracture emanating from the first wellbore, and wherein the first fluid increases a minimum horizontal stress of the formation in a second volume of the formation substantially surrounding at least a second fracture emanating from the first wellbore; wherein a third volume of the formation is located at least partially between the first volume and the second volume, and wherein the third volume has a minimum horizontal stress of the formation below both the minimum horizontal stress in the first volume and the minimum horizontal stress in the second volume after the first fluid increases the minimum horizontal stresses in the first volume and the second volume; forming one or more additional fractures from a second wellbore in the formation, the second wellbore being substantially parallel to the first wellbore, wherein at least one of the additional fractures emanates from the second wellbore and propagates into the third volume of the formation; producing at least some hydrocarbons from the second wellbore; and following said step of forming one or more additional fractures from the second wellbore in the formation, providing a second fluid into the first wellbore. ### Claim 16 (depends on 15) The method of claim 15, wherein the first wellbore comprises a substantially horizontal wellbore in the formation. ### Claim 17 (depends on 15) The method of claim 15, wherein the increased minimum horizontal stress in the first zone is at least about 500 psi greater than the minimum horizontal stress in the third zone. ### Claim 18 (depends on 15) The method of claim 15, wherein the increased minimum horizontal stress in the second zone is at least about 500 psi greater than the minimum horizontal stress in the third zone. ### Claim 19 (depends on 15) The method of claim 15, wherein the first wellbore is positioned in a portion of the subsurface formation with an average matrix permeability of at most about 1 mD. ### Claim 20 (depends on 15) The method of claim 15, wherein the first fluid comprises at least about 95% by weight water. ### Claim 21 (depends on 15) The method of claim 15, wherein the first fluid comprises carbon dioxide, natural gas, or a combination thereof. ### Claim 22 (depends on 15) The method of claim 15, wherein the second fluid comprises at least about 95% by weight water. ### Claim 23 (depends on 15) The method of claim 15, wherein the second fluid comprises carbon dioxide, natural gas, or a combination thereof. ### Claim 24 (depends on 15) The method of claim 15, wherein the additional fracture that propagates into the third zone is inhibited from intersecting with the fractures emanating from the first wellbore. ### Claim 25 (depends on 15) The method of claim 15, further comprising controlling a rate of injection of the first fluid and a total injection volume of the first fluid to control a size of the first zone, a size of the second zone, and a size of the third zone such that the additional fracture that propagates into the third zone does not intersect with the fractures emanating from the first wellbore. ### Claim 26 (depends on 15) The method of claim 15, further comprising providing the first fluid into the first wellbore at an injection rate of at most about 50 bbl/min. ### Claim 27 (depends on 15) The method of claim 15, wherein the one or more additional fractures from the second wellbore are formed by stimulating the wellbore with fracturing fluids.