Abstract: The complexity of a fracture network may be enhanced during a hydraulic fracturing operation by monitoring operational parameters of the fracturing job and altering stress conditions in the well in response to the monitoring of the operational parameters. The operational parameters monitored may include the injection rate of the pumped fluid, the density of the pumped fluid or the bottomhole pressure of the well after the fluid is pumped. The method provides an increase to the stimulated reservoir volume (SRV).

Abstract: A method of fracturing a subterranean formation penetrated by a well comprises: forming a fracturing composition comprising a carrier fluid; and a superabsorbent polymer component comprising one or more of the following: a first composite of a proppant and a first superabsorbent polymer in an unhydrated form, the first superabsorbent polymer being at least partially embedded in a void area of the proppant; a coated superabsorbent polymer; a superabsorbent material having a three-dimensional network; or a second composite of a second superabsorbent polymer and a slow-release breaker; and pumping the hydraulic fracturing composition into the subterranean formation to create or enlarge a fracture.

Abstract: A method of enhancing conductivity within a hydrocarbon-bearing reservoir by building proppant pillars in a spatial arrangement in fractures created or enlarged in the reservoir. Two fluids of differing stability are simultaneously pumped into the reservoir. The fluids may contain identical proppant mixtures which include a first proppant which has an apparent specific gravity less than the apparent specific gravity of a second proppant. The fluids may contain identical proppants mixtures where the average particle size of a first proppant is greater than the average particle size of a second proppant. Vertically extending pillars are created within the formation when the fluids are destabilized and the first proppant is then released from the destabilized fluids. The area between the pillars may be held open by the presence of the second proppant in the remaining fluid.

Abstract: The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is pumped into the formation and into a lower permeability zone farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production of hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Abstract: A method of fracturing a subterranean formation penetrated by a well comprises: forming a fracturing composition comprising a carrier fluid; and a superabsorbent polymer component comprising one or more of the following: a first composite of a proppant and a first superabsorbent polymer in an unhydrated form, the first superabsorbent polymer being at least partially embedded in a void area of the proppant; a coated superabsorbent polymer; a superabsorbent material having a three-dimensional network; or a second composite of a second superabsorbent polymer and a slow-release breaker; and pumping the hydraulic fracturing composition into the subterranean formation to create or enlarge a fracture.

Abstract: A method of fracturing a subterranean formation penetrated by a well comprises: forming a fracturing composition comprising a carrier fluid; and a superabsorbent polymer component comprising one or more of the following: a first composite of a proppant and a first superabsorbent polymer in an unhydrated form, the first superabsorbent polymer being at least partially embedded in a void area of the proppant; a coated superabsorbent polymer; a superabsorbent material having a three-dimensional network; or a second composite of a second superabsorbent polymer and a slow-release breaker; and pumping the hydraulic fracturing composition into the subterranean formation to create or enlarge a fracture.

Abstract: A method of enhancing conductivity within a hydrocarbon-bearing reservoir by building proppant pillars in a spatial arrangement in fractures created or enlarged in the reservoir. Two fluids of differing stability are simultaneously pumped into the reservoir. The fluids may contain identical proppant mixtures which include a first proppant which has an apparent specific gravity less than the apparent specific gravity of a second proppant. The fluids may contain identical proppants mixtures where the average particle size of a first proppant is greater than the average particle size of a second proppant. Vertically extending pillars are created within the formation when the fluids are destabilized and the first proppant is then released from the destabilized fluids. The area between the pillars may be held open by the presence of the second proppant in the remaining fluid.

Abstract: The complexity of a fracture network may be enhanced during a hydraulic fracturing operation by monitoring operational parameters of the fracturing job and altering stress conditions in the well in response to the monitoring of the operational parameters. The operational parameters monitored may include the injection rate of the pumped fluid, the density of the pumped fluid or the bottomhole pressure of the well after the fluid is pumped. The method provides an increase to the stimulated reservoir volume (SRV).

Abstract: A segregating fluid for use in a wellbore includes an aqueous segregating carrier fluid; and a preformed synthetic polymer swellable in the aqueous segregating carrier fluid in an amount effective to segregate a first fluid from a second fluid in a wellbore.

Abstract: A method of drilling a wellbore in a subterranean formation comprises circulating a water-based or oil-based drilling fluid in the subterranean formation; the water-based or oil-based drilling fluid comprising a carrier, and a superabsorbent polymer present in an amount effective to reduce fluid leakoff during the drilling operation, the superabsorbent polymer comprising crosslinks formed before the superabsorbent polymer is combined with the carrier.

Abstract: A cement spacer fluid for use in a wellbore includes an aqueous cement spacer carrier fluid and a preformed synthetic polymer swellable in the aqueous cement spacer carrier fluid in an amount effective to displace a drilling fluid during a cementing operation. Preferably, the polymer is particulate, and forms a hydrated pack of particles. A method of cementing a wellbore comprising a drilling fluid includes injecting the cement spacer fluid into the wellbore to displace the drilling fluid; injecting a cement slurry into the wellbore subsequent to injecting the cement spacer fluid; and hardening the cement in the slurry to cement the wellbore.

Abstract: The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Abstract: The complexity of a fracture network may be enhanced during a hydraulic fracturing operation by monitoring operational parameters of the fracturing job and altering stress conditions in the well in response to the monitoring of the operational parameters. The operational parameters monitored may include the injection rate of the pumped fluid, the density of the pumped fluid or the bottomhole pressure of the well after the fluid is pumped. The method provides an increase to the stimulated reservoir volume (SRV).

Abstract: A method of enhancing conductivity within a hydrocarbon-bearing reservoir by building proppant pillars in a spatial arrangement in fractures created or enlarged in the reservoir. Two fluids of differing viscosity and stability are simultaneously pumped into the reservoir. The fluids contain identical proppants which include a proppant which is neutrally buoyant in the fluid and a proppant which is not neutrally buoyant in the fluid. Vertically extending pillars are created within the formation when the fluids are destabilized and the heavier proppant is then released from the destabilized fluids. The area between the pillars may be held open by the presence of the neutrally buoyant proppant in the remaining fluid. Fluid produced from the hydrocarbon-bearing reservoir is then flowed at least partially through channels between the vertically extending pillars.

Abstract: A method of enhancing conductivity within a hydrocarbon-bearing reservoir by building proppant pillars in a spatial arrangement in fractures created or enlarged in the reservoir. Two fluids of differing viscosity and stability are simultaneously pumped into the reservoir. The fluids contain identical proppants which include a proppant which is neutrally buoyant in the fluid and a proppant which is not neutrally buoyant in the fluid. Vertically extending pillars are created within the formation when the fluids are destabilized and the heavier proppant is then released from the destabilized fluids. The area between the pillars may be held open by the presence of the neutrally buoyant proppant in the remaining fluid. Fluid produced from the hydrocarbon-bearing reservoir is then flowed at least partially through channels between the vertically extending pillars.

Abstract: Disclosed herein is a foamed fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; a foaming agent; and a gas constituent, the synthetic polymer, foaming agent and gas constituent being operative to increase the viscosity of the carrier fluid to about 50 centipoise or greater at 100 s?1, the foamed fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation. A method for treating a hydrocarbon-bearing formation is also disclosed herein.

Abstract: A cement isolation fluid for use in a wellbore during a cementing operation includes an aqueous carrier fluid and a preformed synthetic polymer swellable in the carrier fluid, in an amount effective to isolate a cement slurry from another drilling fluid present in the wellbore. A method of cementing a wellbore comprising a drilling fluid includes injecting the cement isolation fluid into the wellbore; injecting a cement slurry into the wellbore; and hardening the cement in the slurry to cement the wellbore.

Abstract: A method for building a plug in a horizontal wellbore using a fluid pill containing a suspended well treatment composite. The well treatment composite contains a core comprising at least one deformable particulate and at least one dissolvable diverter. At least a portion of the surface of the core is coated with at least one viscosifying polymer and at least one crosslinking agent. The fluid pill is pumped into the wellbore at the end of a fracturing treatment and the fluid pill may be displaced by a displacement fluid. The fluid pill may be diverted to an area of lower permeability by disassociating the dissolvable diverter from the core. The disassociated diverter blocks an area of higher permeability. The sized particle distribution of the diverter is sufficient to at least partially block the penetration of fluid into the high permeability zone. In the lower permeability zone, a thickened gel is formed by the in-situ reaction of the viscosifying polymer and crosslinking.

Abstract: The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Abstract: A method of drilling a wellbore in a subterranean formation comprises circulating a water-based or oil-based drilling fluid in the subterranean formation; the water-based or oil-based drilling fluid comprising a carrier, and a superabsorbent polymer present in an amount effective to reduce fluid leakoff during the drilling operation, the superabsorbent polymer comprising crosslinks formed before the superabsorbent polymer is combined with the carrier.