Abstract: A workflow for fracturing a subterranean formation includes providing fracturing databases or models for the hydrocarbon wellbore, selecting one or more fracturing fluid systems for fracturing the subterranean formation based on the fracturing databases or models and recommending at least one of the one or more selected fracturing fluid systems for fracturing the subterranean formation. Additionally, a workflow controller for fracturing a subterranean formation includes a workflow processing unit having fracturing models or databases to determine functional aspects of one or more fracturing fluid systems to provide a fracturing fluid system recommendation for the subterranean formation, and a fracturing fluid delivery unit that applies the fracturing fluid system recommendation to the subterranean formation. A hydrocarbon wellbore fracturing system for a subterranean formation is also provided.

Abstract: System and methods of controlling fluid flow during reservoir stimulation treatments are provided. A flow distribution of treatment fluid injected into formation entry points along a wellbore path is monitored during a current stage of a multistage stimulation treatment. Upon determining that the monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase for diverting the fluid to be injected away from one or more formation entry points between consecutive treatment cycles. A portion of the fluid to be injected into the formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: System and methods of optimizing proppant placement for stimulation treatments are provided. Properties of a reservoir formation and a treatment fluid to be injected into the formation are determined for a multistage stimulation treatment to be performed along a wellbore drilled within the formation. A proppant transport model uses the properties to determine a proppant profile for a fractured area of the formation for each treatment stage along the wellbore. A proppant pack conductivity for each stage is determined based on a proppant conductivity model and the proppant profile for that stage. A rate of hydrocarbon production expected from the wellbore is estimated based on a well production model and the proppant pack conductivity. A distribution of proppant to be injected into the formation during the treatment is determined, based on the production rate and one or more constraints. The stimulation treatment is performed based on the determined proppant distribution.

Abstract: Creating a fracture network extending from a wellbore into a subterranean formation. The method includes introducing a series of fluids into the fracture network in a subterranean formation, thereby forming a proppant pack in the fracture network. The series of fluids comprise: a microproppant slurry comprising a microproppant having an average diameter less than about 25 microns; a proppant slurry comprising a proppant having an average diameter of about 75 microns to about 500 microns; and a sweep fluid having a microproppant weight percentage by weight of the sweep fluid that is from 0 to about the same of the microproppant weight percentage in the microproppant slurry by weight of the microproppant slurry. The introduction of the microproppant slurry is not immediately followed by introduction of the proppant slurry. The introduction of the proppant slurry is not immediately followed by introduction of the microproppant slurry.

Abstract: A wellbore fracturing system that includes wellbore fracturing resources coupled through a wellbore conveyance to a subterranean formation of the wellbore; The wellbore fracturing system further includes a bottom hole pressure gauge that provides a bottom hole gauge pressure, and a processor coupled to the wellbore fracturing resources and the wellbore conveyance that calculates a wellbore friction pressure using a time-series sampling of bottom-hole gauge pressures for a fracturing fluid system after a uniform fracturing fluid condition is achieved in the wellbore. Also included are methods of calculating and managing a wellbore friction pressure.

Abstract: System and methods of optimizing proppant placement for stimulation treatments are provided. Properties of a reservoir formation and a treatment fluid to be injected into the formation are determined for a multistage stimulation treatment to be performed along a wellbore drilled within the formation. A proppant transport model uses the properties to determine a proppant profile for a fractured area of the formation for each treatment stage along the wellbore. A proppant pack conductivity for each stage is determined based on a proppant conductivity model and the proppant profile for that stage. A rate of hydrocarbon production expected from the wellbore is estimated based on a well production model and the proppant pack conductivity. A distribution of proppant to be injected into the formation during the treatment is determined, based on the production rate and one or more constraints. The stimulation treatment is performed based on the determined proppant distribution.

Abstract: A wellbore fracturing system that includes wellbore fracturing resources coupled through a wellbore conveyance to a subterranean formation of the wellbore; The wellbore fracturing system further includes a bottom hole pressure gauge that provides a bottom hole gauge pressure, and a processor coupled to the wellbore fracturing resources and the wellbore conveyance that calculates a wellbore friction pressure using a time-series sampling of bottom-hole gauge pressures for a fracturing fluid system after a uniform fracturing fluid condition is achieved in the wellbore. Also included are methods of calculating and managing a wellbore friction pressure.

Abstract: A workflow for fracturing a subterranean formation includes providing fracturing databases or models for the hydrocarbon wellbore, selecting one or more fracturing fluid systems for fracturing the subterranean formation based on the fracturing databases or models and recommending at least one of the one or more selected fracturing fluid systems for fracturing the subterranean formation. Additionally, a workflow controller for fracturing a subterranean formation includes a workflow processing unit having fracturing models or databases to determine functional aspects of one or more fracturing fluid systems to provide a fracturing fluid system recommendation for the subterranean formation, and a fracturing fluid delivery unit that applies the fracturing fluid system recommendation to the subterranean formation. A hydrocarbon wellbore fracturing system for a subterranean formation is also provided.

Abstract: Various embodiments disclosed relate to compositions including acidic chelator or salt or ester thereof for treatment of subterranean formations including one or more fractures. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a composition including an acidic chelator or a salt or ester thereof. The subterranean formation includes one or more fractures.

Abstract: Methods including introducing a solids-free high-viscosity fracturing fluid into a subterranean formation above the fracture gradient to create or enhance at least one dominate fracture. Introducing a first low-viscosity pad fluid (LVPadF) above the fracture gradient to create or enhance at least one first microfracture extending from the dominate fracture. The first LVPadF comprises an aqueous base fluid, high-density micro-proppants (HDMPs), and low-density micro-beads (LDMBs), the HDMPs having a specific gravity that is at least about 100% greater than the specific gravity of the LDMBs. Placing at least a portion of the HDMPs and LDMBs into the microfracture to form at least a partial monolayer. Introducing a low-viscosity proppant fluid (LVPropF) into the subterranean formation above the fracture gradient. The LVPropF comprises an aqueous base fluid and medium-sized proppants (MSPs). Placing at least a portion of the MSPs into the dominate fracture.

Abstract: A method comprises creating a fracture network extending from a wellbore into a subterranean formation; then, introducing a series of fluids into the fracture network in a subterranean formation, thereby forming a proppant pack in the fracture network, wherein the series of fluids comprise: a microproppant slurry comprising a microproppant having an average diameter less than about 25 microns; a proppant slurry comprising a proppant having an average diameter of about 75 microns to about 500 microns; and a sweep fluid having a microproppant weight percentage by weight of the sweep fluid that is from 0 to about the same of the microproppant weight percentage in the microproppant slurry by weight of the microproppant slurry; and wherein introduction of the microproppant slurry is not immediately followed by introduction of the proppant slurry, and wherein introduction of the proppant slurry is not immediately followed by introduction of the microproppant slurry.

Abstract: System and methods of controlling fluid flow during reservoir stimulation treatments are provided. A flow distribution of treatment fluid injected into formation entry points along a wellbore path is monitored during a current stage of a multistage stimulation treatment. Upon determining that the monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase for diverting the fluid to be injected away from one or more formation entry points between consecutive treatment cycles. A portion of the fluid to be injected into the formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: The present disclosure relates to systems and methods for using aldehydes as a catalyst for oxidative breakers. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid, a polymeric gelling agent, a breaker that comprises an oxidative salt, and a catalyst that comprises an aldehyde; allowing the breaker to interact with the polymeric gelling agent; and allowing the viscosity of the treatment fluid to reduce.

Abstract: Methods including introducing a solids-free high-viscosity fracturing fluid into a subterranean formation above the fracture gradient to create or enhance at least one dominate fracture. Introducing a first low-viscosity pad fluid (LVPadF) above the fracture gradient to create or enhance at least one first microfracture extending from the dominate fracture. The first LVPadF comprises an aqueous base fluid, high-density micro-proppants (HDMPs), and low-density micro-beads (LDMBs), the HDMPs having a specific gravity that is at least about 100% greater than the specific gravity of the LDMBs. Placing at least a portion of the HDMPs and LDMBs into the microfracture to form at least a partial monolayer. Introducing a low-viscosity proppant fluid (LVPropF) into the subterranean formation above the fracture gradient. The LVPropF comprises an aqueous base fluid and medium-sized proppants (MSPs). Placing at least a portion of the MSPs into the dominate fracture.

Abstract: A fluid comprising: an aqueous phase; a cellulose derivative dispersed or dissolved in the aqueous phase; a guar derivative dispersed or dissolved in the aqueous phase; a titanium crosslinker dispersed or dissolved in the aqueous phase; and a zirconium crosslinker dispersed or dissolved in the aqueous phase. A method of treating a well or a well system can include: (A) forming a treatment fluid according to the disclosure; and (B) introducing the treatment fluid into a treatment zone of a well.

Abstract: Various embodiments disclosed relate to compositions including acidic chelator or salt or ester thereof for treatment of subterranean formations including one or more fractures. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a composition including an acidic chelator or a salt or ester thereof. The subterranean formation includes one or more fractures.

Abstract: The present disclosure relates to systems and methods for using aldehydes as a catalyst for oxidative breakers. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid, a polymeric gelling agent, a breaker that comprises an oxidative salt, and a catalyst that comprises an aldehyde; allowing the breaker to interact with the polymeric gelling agent; and allowing the viscosity of the treatment fluid to reduce.

Abstract: A method is provided for improved degradation of metal-crosslinked polymer gels, which are useful in oil and gas treating operations. In this method a polysaccharide having a higher degree of substitution than the polymer in the polymer gel is added to the gel. The polysaccharide removes the crosslinking metal ion from the gel to thus break down the gel and reduce its viscosity.

Abstract: Introducing a treatment fluid comprising proppant particulates into a subterranean formation, the treatment fluid comprising a high salt concentration base fluid, a charged polymeric gelling agent, and proppant particulates suspended therein, wherein the high salt concentration base fluid comprises a concentration of salt in the range of from about 0.5% to saturation, and wherein the treatment fluid has a bulk viscosity of from about 30 cP to about 150 cP at a shear rate of about 40 sec?1.

Abstract: Viscosified treatment fluids that include polyol derivatized cellulose may be useful in subterranean operations. For example, a method may include introducing a viscosified treatment fluid into a wellbore penetrating a subterranean formation, wherein the viscosified treatment fluid comprises an aqueous base fluid, borate ions, and a polyol derivatized cellulose, and wherein the polyol derivatized cellulose comprise a cellulosic backbone derivatized with pendants comprising (1) a terminal polyol and (2) at least one of an internal 1,2,3-triazole, an internal ester, and an internal amide.