# US 10,119,376 B2 · Methods and systems for maintaining a pressure differential between pairs of packers > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,119,376 B2 - Document ID: US10119376B2 - Status: Granted - Kind: B2 - Application number: 15/267,005 - Filed: 2016-09-15 - Published: 2018-03-15 - Granted: 2018-11-06 - Earliest claimed: 2016-09-15 - Assignees: Comitt Well Solutions US Holding Inc. - Applicants: Comitt Well Solutions US Holding Inc. - Inventors: Peter Kris Cleven - Web page: https://patentgrep.com/patent/US10119376B2 ## CPC - E21B 43/25: Methods for stimulating production {(by vibrating earth formations E21B43/003)} - E21B 33/122: Multiple string packers - E21B 33/124: Units with longitudinally-spaced plugs for isolating the intermediate space - E21B 34/08: responsive to flow or pressure of the fluid obtained (E21B34/10 takes precedence) - E21B 43/14: Obtaining from a multiple-zone well - E21B 43/26: by forming crevices or fractures - 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 Examples of the present disclosure relate to systems and methods for fracturing systems that maintain a substantially constant pressure differential between a first pressure zone and a second pressure zone. ## Claims ### Claim 1 A system for stimulating a well comprising: a flow activated valve positioned proximate to a distal end of a tool, the flow activated valve being configured to move towards the distal end to the tool to seal a hole located at the distal most end of the tool responsive to flowing fluid through an inner diameter of the tool; a packer pair configured to expand responsive to the flow activated valve sealing the distal most end of the tool, the packer pair including an upper packer and a lower packer; a vent including a first end positioned above the lower packer and a second end positioned below the lower packer, the second end of the vent being coupled with a sliding sleeve, the sliding sleeve being configured to cover a vent hole through the tool responsive to the packer pair sealing against a wellbore wall, the vent hole extending laterally through the tool from the inner diameter of the tool to an annulus; a first pressure zone positioned within the inner diameter of the tool; a second pressure zone positioned outside of the tool between the upper packer and the lower packer; a linearly adjustable member configured to maintain a substantially constant pressure differential between the first pressure zone and the second pressure zone when the packers are sealing against the wellbore wall. ### Claim 2 (depends on 1) The system of claim 1, further comprising: a third pressure zone positioned outside of the the tool below the lower packer, wherein when the sliding sleeve covers the vent hole the third pressure zone is not in communication with the first pressure zone or the second pressure zone. ### Claim 3 (depends on 2) The system of claim 2, wherein the flow activated valve is configured to not seal the distal most end of the tool responsive to ceasing the fluid flowing through the inner diameter of the tool, and when ceasing the fluid flow through the inner diameter of the tool the sliding sleeve does not cover the vent hole. ### Claim 4 (depends on 3) The system of claim 3, wherein the first pressure zone, the second pressure zone, and the third pressure zone are in communication with each other when the sliding sleeve does not cover the vent hole. ### Claim 5 (depends on 4) The system of claim 4, wherein the flow activated valve is deactivated when ceasing the fluid flowing through the inner diameter of the tool based on the communication between the first pressure zone, the second pressure zone, and the third pressure zone. ### Claim 6 (depends on 1) The system of claim 1, further comprising; a gate configured to move in a linear axis in parallel to the longitudinal axis of the tool and to cover a valve when the flow activated valve is not sealing the distal most end of the tool. ### Claim 7 (depends on 6) The system of claim 6, wherein the gate is configured to not cover the valve when the flow activated valve is sealing the distal most end of the tool. ### Claim 8 (depends on 6) The system of claim 6, wherein the gate is positioned between the upper packer and the lower packer. ### Claim 9 (depends on 1) The system of claim 1, wherein the substantially constant pressure differential is a positive value. ### Claim 10 (depends on 1) The system of claim 1, wherein the linearly adjustable member is configured to compress as a fluid flow rate through the inner diameter of the tool increases to maintain a substantially constant pressure differential. ### Claim 11 A method for stimulating a well comprising: positioning a flow activated valve proximate to a distal end of a tool; moving the flow activated valve towards the distal end of the tool to seal a hole positioned on the distal most end of the tool responsive to flowing fluid through an inner diameter of the tool; expanding a packer pair responsive to the flow activated valve sealing the distal most end of the tool, the packer pair including an upper packer and a lower packer; moving a sliding sleeve coupled to a vent to cover a vent hole, the vent hole extending laterally through the tool from the inner diameter of the tool to an annulus responsive to the packer pair sealing against a wellbore wall, wherein the vent includes a first end positioned above the lower packer and a second end positioned below the lower packer, the sliding sleeve being coupled to the second end; creating a first pressure zone positioned within the inner diameter of the tool; creating a second pressure zone positioned outside the the tool between the upper packer and the lower packer; maintaining, via a linearly adjustable member, a substantially constant pressure differential between the first pressure zone and the second pressure zone when the packers are sealing against the wellbore wall. ### Claim 12 (depends on 11) The method of claim 11, further comprising: creating a third pressure zone positioned outside of the the tool below the lower packer, wherein when the sliding sleeve covers the vent hole the third pressure zone is not in communication with the first pressure zone or the second pressure zone. ### Claim 13 (depends on 12) The method of claim 12, further comprising: not sealing the distal most end of the tool by the flow activated valve responsive to ceasing the fluid flowing through the inner diameter of the tool, and when ceasing the fluid flow through the inner diameter of the tool the sliding sleeve does not cover the vent hole. ### Claim 14 (depends on 13) The method of claim 13, wherein the first pressure zone, the second pressure zone, and the third pressure zone are in communication with each other when the sliding sleeve does not cover the vent hole. ### Claim 15 (depends on 14) The method of claim 14, further comprising: de-activing the flow activated valve when ceasing the fluid flowing through the inner diameter of the tool based on the communication between the first pressure zone, the second pressure zone, and the third pressure zone. ### Claim 16 (depends on 11) The method of claim 11, further comprising: moving a gate configured in a linear axis in parallel to the longitudinal axis of the tool to cover a valve when the flow activated valve is not sealing the distal most end of the tool. ### Claim 17 (depends on 16) The method of claim 16, wherein the gate is configured to not cover the valve when the flow activated valve is sealing the distal most end of the tool. ### Claim 18 (depends on 16) The method of claim 16, wherein the gate is positioned between the upper packer and the lower packer. ### Claim 19 (depends on 11) The method of claim 11, wherein the substantially constant pressure differential is a positive value. ### Claim 20 (depends on 11) The method of claim 11, further comprising: compressing the linearly adjustable member configured as a fluid flow rate through the inner diameter of the tool increases to maintain a substantially constant pressure differential.