# US 10,309,208 B2 · Enhancing propped complex fracture networks > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,309,208 B2 - Document ID: US10309208B2 - Status: Granted - Kind: B2 - Application number: 15/772,795 - Filed: 2016-02-03 - Published: 2018-11-08 - Granted: 2019-06-04 - Earliest claimed: 2016-02-03 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Philip D. Nguyen; Walter T. Stephens - Web page: https://patentgrep.com/patent/US10309208B2 ## CPC - E21B 43/267: reinforcing fractures by propping - C09K 8/40: Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses - C09K 8/601: {using spacer compositions} - C09K 8/62: Compositions for forming crevices or fractures - C09K 8/80: Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE ## Abstract Methods including introducing a solids-free high-viscosity fracturing fluid (HVFF) into a subterranean formation to create or enhance at least one dominate fracture, introducing a low-viscosity pad fluid (LVPadF) into the subterranean formation above the fracture gradient pressure to create or enhance at least one first microfracture, wherein the LVPadF comprises micro-proppant, and placing at least a portion of the micro-proppant into the at least one first microfracture. Alternatingly introducing a first low-viscosity proppant fluid (LVPropF) and a high-viscosity crosslinked spacer fluid (HVCSF) into the subterranean formation, wherein the first LVPropF comprises proppant aggregates and the HVCSF comprises a gelling agent, a crosslinking agent, and a breaker, and placing at least a portion of the proppant aggregates into the dominate fracture, where the HVCSF separates clusters of proppant aggregates in the dominate fracture. Then, removing hydraulic pressure from the subterranean formation and activating the breaker in the HVCSF. ## Claims ### Claim 1 A method comprising: (a) introducing a solids-free high-viscosity fracturing fluid (HVFF) into a subterranean formation at a first perforated interval above a fracture gradient pressure to create or enhance a dominate fracture in a first treatment interval therein; (b) then introducing a low-viscosity pad fluid (LVPadF) into the subterranean formation at the first perforated interval above the fracture gradient pressure to create or enhance a first microfracture extending from the dominate fracture, whereby the dominate fracture continues to grow in length as the first microfracture is created or enhanced; wherein the LVPadF comprises a first base fluid and micro-proppant, (c) placing at least a portion of the micro-proppant into the first microfracture; (d) then alternatingly introducing a first low-viscosity proppant fluid (LVPropF) and a high-viscosity crosslinked spacer fluid (HVCSF) into the subterranean formation at the first perforated interval, wherein the first LVPropF comprises a second base fluid and proppant aggregates, and wherein the HVCSF comprises a third base fluid, a gelling agent, a crosslinking agent, and a breaker; (e) placing at least a portion of the proppant aggregates into the dominate fracture, where the HVCSF separates clusters of proppant aggregates in the dominate fracture; (f) then removing hydraulic pressure from the subterranean formation; and (g) activating the breaker in the HVCSF; wherein the high-viscosity fluids each have a viscosity of about 50 cP to about 20000 cP and the low-viscosity fluids each have a viscosity of about 1 cP to about 100 cP. ### Claim 2 (depends on 1) The method of claim 1, further comprising performing (e1) after (e), (e1) comprising introducing a second LVPropF comprising a fourth base fluid and proppant particulates, and placing the proppant particulates in a near-wellbore region of the dominate fracture to form a proppant pack therein. ### Claim 3 (depends on 1) The method of claim 1, further comprising performing (e1) after (e), (e1) comprising introducing a second LVPropF comprising a fourth base fluid, proppant particulates, and degradable particulates, and placing the proppant particulates and the degradable particulates in a near-wellbore region of the dominate fracture to form a proppant pack therein. ### Claim 4 (depends on 1) The method of claim 1, wherein the proppant aggregates further comprise degradable particulates. ### Claim 5 (depends on 1) The method of claim 1, wherein the first LVPropF further comprises degradable particulates. ### Claim 6 (depends on 1) The method of claim 1, further comprising repeating one or more of (a) through (g) at the first perforated interval in the subterranean formation. ### Claim 7 (depends on 1) The method of claim 1, further comprising repeating (a) through (g) at at least a second perforated interval in the subterranean formation. ### Claim 8 (depends on 1) The method of claim 1, wherein the HVCSF further comprises micro-proppant. ### Claim 9 (depends on 1) The method of claim 1, wherein the proppant aggregates comprise proppant particulates and a binding agent, and the proppant particulates have a crush resistance of greater than about 10% fines when exposed to downhole closure stress and temperature in the subterranean formation. ### Claim 10 (depends on 1) The method of claim 1, further comprising a tubular extending from a wellhead and into the subterranean formation forming an annulus between the tubular and the subterranean formation, and a pump fluidly coupled to the tubular, the tubular or the annulus containing a fluid selected from the group consisting of the HVFF, the LVPadF, the first LVPropF, the HVCSF, and any combination thereof. ### Claim 11 A method comprising: (a) introducing a solids-free high-viscosity fracturing fluid (HVFF) into a subterranean formation at a first perforated interval above a fracture gradient pressure to create or enhance a dominate fracture in a first treatment interval therein; (b) then introducing a low-viscosity pad fluid (LVPadF) into the subterranean formation at the first perforated interval above the fracture gradient pressure to create or enhance a first microfracture extending from the dominate fracture, whereby the dominate fracture continues to grow in length as the first microfracture is created or enhanced; wherein the LVPadF comprises a first base fluid and micro-proppant, (c) placing at least a portion of the micro-proppant into the first microfracture; (d) then simultaneously introducing a first low-viscosity proppant fluid (LVPropF) and a high-viscosity crosslinked spacer fluid (HVCSF) into the subterranean formation at the first perforated interval, wherein the first LVPropF comprises a second base fluid and proppant aggregates, and wherein the HVCSF comprises a third base fluid, a gelling agent, a crosslinking agent, and a breaker; (e) placing at least a portion of the proppant aggregates into the dominate fracture, where the HVCSF separates clusters of proppant aggregates in the dominate fracture; (f) then removing hydraulic pressure from the subterranean formation; and (g) activating the breaker in the HVCSF; wherein the high-viscosity fluids each have a viscosity of about 50 cP to about 20000 cP and the low-viscosity fluids each have a viscosity of about 1 cP to about 100 cP. ### Claim 12 (depends on 11) The method of claim 11, wherein one of the LVPropF or the HVCSF is introduced into the subterranean formation through a tubular and the other is introduced into the subterranean formation through an annulus formed between the tubular and the subterranean formation, wherein the first LVPropF and the HVCSF do not contact one another until reaching the first perforated interval. ### Claim 13 (depends on 11) The method of claim 11, further comprising performing (e1) after (e), (e1) comprising introducing a second LVPropF comprising a fourth base fluid and proppant particulates, and placing the proppant particulates in a near-wellbore region of the dominate fracture to form a proppant pack therein. ### Claim 14 (depends on 11) The method of claim 11, further comprising performing (e1) after (e), (e1) comprising introducing a second LVPropF comprising a fourth base fluid, proppant particulates, and degradable particulates, and placing the proppant particulates and the degradable particulates in a near-wellbore region of the dominate fracture to form a proppant pack therein. ### Claim 15 (depends on 11) The method of claim 11, wherein the first LVPropF further comprises degradable particulates. ### Claim 16 (depends on 11) The method of claim 11, further comprising repeating one or more of (a) through (g) at the first perforated interval in the subterranean formation. ### Claim 17 (depends on 11) The method of claim 11, further comprising repeating (a) through (g) at at least a second perforated interval in the subterranean formation. ### Claim 18 (depends on 11) The method of claim 11, wherein the HVCSF further comprises micro-proppant. ### Claim 19 (depends on 11) The method of claim 11, wherein the proppant aggregates comprise proppant particulates and a binding agent, and the proppant particulates have a crush resistance of greater than about 10% fines when exposed to downhole closure stress and temperature in the subterranean formation. ### Claim 20 (depends on 11) The method of claim 11, further comprising a tubular extending from a wellhead and into the subterranean formation forming an annulus between the tubular and the subterranean formation, and a pump fluidly coupled to the tubular, the tubular or the annulus containing a fluid selected from the group consisting of the HVFF, the LVPadF, the first LVPropF, the HVCSF, and any combination thereof.