Abstract: A method of producing oil which begins by drilling, casing and inserting a tubing string in a wellbore. The method then perforates both an upper portion and a lower portion of the casing to establish communication between the wellbore with a upper horizontal fracture and a lower horizontal fracture. A retrievable packer or a seal assembly is inserted horizontally between the tubing string and the casing and vertically between the upper horizontal fracture and the lower horizontal fracture for heat isolation. Steam is then injected into the wellbore both into the upper horizontal fracture and the lower horizontal fracture.

Abstract: A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%.

Abstract: Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to stochastic simulation of subterranean fracture propagation. A plurality of subterranean formation models, each representing a subterranean formation, are analyzed to obtain information on predicted results of applying an injection treatment to the subterranean formation. Each of the analyzed subterranean formation models is generated by simulating forces acting on rock blocks of the subterranean formation during the injection treatment. Each simulation has an input parameter value determined for that simulation based on sampling a distribution of values for a characteristic of the subterranean formation. The characteristic may include, for example, a natural fracture parameter. The information on the predicted results of applying the injection treatment may include, for example, an output probability distribution.

Abstract: A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant (16) wherein the proppant comprises from 1 to 100 percent in weight of stiff, low-elasticity and low-deformability elongated particles (34) and proppant-spacing filler material called a channelant (18) through a wellbore (10) into the fracture (20), heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands (22) spaced apart by the channelant (24), and removing the channelant filler material (24) to form open channels (26) around the pillars (28) for fluid flow from the formation (14) through the fracture (20) toward the wellbore (10). The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture.

Abstract: Apparatus and methods of reducing the viscosity of a gelled fluid is provided. In one embodiment, a viscosity reducing microbe is disposed in a capsule and added to the gelled fluid. The gelled fluid may include a thickening agent adapted to increase its viscosity. Upon release from the capsule, the microbe begins to digest the thickening agent in the gelled fluid and/or releases enzymes that that breakdown the thickening agent.

Abstract: A hydraulic fracturing process consisting essentially of drilling a wellbore through at least one reservoir formation, installing in said wellbore at least one conduit, ensuring pressure communication between said wellbore and said reservoir formation, at a higher effective stress formation, selecting the location of the pressure communication between the wellbore and the reservoir formation for control of said hydraulic fracturing process and pumping a hydraulic fracturing treatment comprising a fracturing fluid and a proppant, at a sufficient pressure via said conduit to create at least one fracture in the higher effective stress formation. In addition, processes for increasing conductivity near a wellbore and producing fluids from a lower effective stress permeable formation via a fracture extending from the higher effective stress fracture formation into the lower effective stress permeable formation may include applying several approaches to packing or filling fractures with proppant.

Abstract: A method is provided for treating at least a portion of a subterranean formation. The method includes the steps of: (a) introducing a treatment fluid into the subterranean formation, wherein the treatment fluid comprises a proppant and a swellable particulate; (b) swelling the swellable particulate, wherein the step of swelling is performed prior to, during, or after the step of introducing the treatment fluid; and (c) degrading the swellable particulate in the subterranean formation, wherein the step of degrading is performed after the steps of introducing and swelling.

Abstract: A substance and method for treating a subterranean formation using hydraulic fracturing. A non-metallic, substantially deformable, proppant particle is “elastically flexible” or “plastically compressible” and adapted for use at concentrations which will substantially create a partial monolayer.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting a first treatment fluid comprising a gas and substantially free of macroscopic particles through a wellbore to initiate a fracture in a subterranean formation; injecting a second treatment fluid comprising proppant and channelant through the wellbore into the fracture; placing the proppant in the fracture in a plurality of proppant clusters forming pillars spaced apart by the channelant; and removing the channelant to form open channels around the pillars for fluid flow from the subterranean formation through the fracture toward the wellbore.

Abstract: The invention relates to the oil-and-gas production industry and can be used for enhancement of the production of oilfield wells as it prevents the fracture from closing by pumping of propping granules (proppant) during the hydraulic fracturing of oil-producing formations. Higher stimulation of a reservoir through using hydraulic fracturing is provided with the proppant as particulate with spherical or elliptic form, made of ceramic, polymer, metal, or glass and having higher roughness than regular proppant, wherein the surface roughness is nonuniform and described by two criteria A and B, varying in the intervals: A =0.0085?0.85; B=0.001?1.0. The proppant manufacturing method comprising the preparation of raw material, mixing, granulation, drying, firing, wherein an additional stage of creation of surface roughness is added at the granulation stage and/or the firing stage.

Abstract: A method and composition for treating a subterranean formation with a fluid, including forming a fluid including a particulate and an organosilane with the chemical formula RnSiX4-n, wherein n is equal to 1, 2, or 3, R is an organic functional group, and X is a halogen, alkoxy, or acetoxy group, introducing the fluid into a subterranean formation with exposed surfaces, and modifying the wettability of a surface of the particulate or subterranean formation or both. A method and composition for treating a subterranean formation with a fluid including forming a fluid comprising a particulate and an organosilane, introducing the fluid into a subterranean formation with exposed surfaces, and modifying the wettability of the proppant or surfaces or both, wherein the wettability modification degrades.

Abstract: In a method of hydraulically fracturing a hydrocarbon-bearing subterranean formation, a proppant stage is introduced into the fracture which contains a gaseous fluid and an ultra lightweight proppant suspended in a viscosified aqueous fluid. The gaseous fluid of the proppant stage contains at least about 90 volume percent of the combination of gaseous fluid and aqueous fluid. A pad fluid may first be introduced into the formation, the pad fluid containing a gaseous fluid and, optionally, an aqueous fluid. The gaseous fluid of the pad fluid mixture typically contains at least 70 volume percent of the mixture.

Abstract: Subterranean treatment fluids that exhibit enhanced particulate transport or suspension capabilities, and associated methods of use in certain subterranean treatments are provided. In one embodiment, the methods comprise: providing a linear gelled fluid that comprises an aqueous base fluid, a plurality of particulates, and a linear particulate transport enhancing additive, the linear gelled fluid having a certain yield stress, crossover frequency, and/or particulate settling time; introducing the linear gelled fluid into the subterranean formation; and using the linear gelled fluid to create or enhance at least one fracture in at least a portion of the subterranean formation.

Abstract: Provided is a system and method for enabling pressure or acoustic waves to induce magnetostrictive volume or shape change, providing greater control over magnetopropants. A coating material and the spacing between a magnetopropant and a magnetic particle are selected such that a certain pressure causes change in the relative distance of magnetopropant and magnetic particle, thereby changing the amount of magnetostriction. The coating material, magnetopropant, and magnetic particle are assembled to form a pressure sensitive magnetopropant. Given this structure, changes in pressure will cause a fluctuation of the amount of magnetostriction. In a pore space environment, this causes a change in pore space with resulting change in permeability and, hence, changes in fluid flow.

Abstract: Hydraulic fracturing an individual reservoir fracturing layer of a subterranean formation to produce heterogeneous proppant placement is given in which pillars of proppant are placed such that the pillars do not extend the entire height of the fracture (for a vertical fracture) but are themselves interrupted by channels so that the channels between the pillars form pathways that lead to the wellbore. The method combines methods of introducing slugs of proppant-carrying and proppant-free fluids through multiple clusters of perforations within a single fracturing layer of rock, with methods of ensuring that the slugs exiting the individual clusters do not merge.

Abstract: A substance and method for treating a subterranean formation using hydraulic fracturing. A non-metallic, substantially deformable, proppant particle is “elastically flexible” or “plastically compressible” and adapted for use at concentrations which will substantially create a partial monolayer.

Abstract: A technique includes running a string into a well bore and inhibiting formation face failure. The well bore extends at least partially through a non-producing layer and a hydrocarbon formation layer. The inhibiting of the formation face failure includes communicating a proppant into the well bore via the string until a well bore pressure exceeds a first formation stress of the non-producing layer, which causes a fracture to form in the non-producing layer, and communicating the proppant into the fracture to create a barrier layer.

Abstract: A composition and method for improving the fluid efficiency of many oilfield treatments is given. The composition is a solid additive, in a viscosified fluid, in a size range small enough that it enters formation pores; it optionally bridges there to form an internal filter cake, and then decomposes to provide a breaker for the viscosifying system for the fluid. Examples of suitable additives include waxes, polyesters, polycarbonates, polyacetals, polymelamines, polyvinyl chlorides, and polyvinyl acetates. Degradation of the additive may be accelerated or delayed.

Abstract: Elimination of sand entrainment and a significant increase in hydrodynamic permeability of the sand pack in an area near the wellbore are achieved through the use of a sand and/or proppant, and proppant material mixture at the final stage of the fracture filling process, where individual particles of the proppant material have at least one shape of plates, lattices, hollow bars, inside-hollow tubes with a closed impermeable cavity or cavities, toroidal particles, elongated particles in the form of ovals, pellets or plates, cylinders with a closed impermeable cavity or cavities, or blocks with a comb multi-channel structure with throughout channels of the ellipse or polygon cross-section.

Abstract: The present invention involves methods of using particulates coated with a tackifying agent that need not be used immediately once they are prepared and that provide increased viscosity when placed into an aqueous fluid. The described methods include the steps of contacting particulates with a tackifying agent to create tackified particulates; contacting the tackified particulates with a partitioning agent to form coated particulates that are capable of being stored for a time period, wherein the partitioning agent comprises a hydratable polymeric material; and, placing the coated particulates in an aqueous treatment fluid whereby the partitioning agent hydrates and increases the viscosity of the treatment fluid.

Abstract: The invention provides a proppant for treating a subterranean formation penetrated by a wellbore, wherein a typical specimen of the proppant has a non-globular and non-fibrous shape. The invention also provides a method for stimulating a subterranean formation penetrated by a wellbore, the method comprising the steps of forming the treatment fluid and introducing the treatment fluid through the wellbore and into the subterranean formation at a sufficient pressure to fracture the formation.

Abstract: Fluid compositions and methods of making and using same are described, one composition comprising a well treatment fluid and an additive combined with the well treatment fluid, wherein the additive is selected from solids, liquids and combinations thereof, the additive having a surface shape, at least one property of the surface shape enabling it to change under influence of a controllable parameter after the composition is deployed into a hydraulic fracture or gravel pack. In methods of the disclosure, the additive exists initially in a first state, and then is changed to a second state. The first state may increase proppant flowback efficiency, while the second state may increase hydraulic conductivity. In certain embodiments, the additive may change back to its first state.

Abstract: This invention relates to the production of minerals, more specifically, to the production of hydrocarbons, by hydraulic fracturing of the rock, and can be used for the optimization of formation fracturing crack processing conditions. Under this invention, the main stream of the propping agent suspension in the fluid at the mixer output is split into at least two flows having different volume delivery rates, and before the delivery to the hydraulic fracturing zone said flows are comingled.

Abstract: A composition for treating solid materials is disclosed, where the treating compositions coats surfaces or portions of surfaces of the solid materials changing an aggregation or agglomeration propensity of the materials. Treated solid materials are also disclosed. The methods and treated materials are ideally suited for oil field applications.

Abstract: Compositions comprising a proppant core having an outer surface and polymeric microspheres attached to at least a portion of the outer surface are described. The compositions are useful, for example, to increase the productivity of a hydrocarbon oil or gas bearing well.

Abstract: Methods of forming and utilizing micro-crosslinked gels are disclosed, including a method comprising: providing a micro-crosslinked gel that comprises micro-domains; and placing the micro-crosslinked gel into a subterranean formation via a well bore penetrating the formation at a desired pressure. In another aspect, the invention provides compositions that include a micro-crosslinked gel comprising a jigsaw configuration of micro-domains and particulates.

Abstract: Methods are disclosed for reducing settling rates of proppants in fracturing fluids, where the method includes injection sufficient gas into the fluid to form bubbles that reduce proppant settling rates. Compositions including a proppants make buoyant with gas bubbles are also disclosed.

Abstract: A subterranean formation stimulation method utilizes a treatment fluid comprising residual drilling fluid injected into the formation, and producing the stimulated formation. In one embodiment, a tight gas formation is fractured and the fracture has a higher conductivity than the formation.

Abstract: A method of treating a subterranean formation penetrated by a wellbore includes preparing a treatment fluid with shear thinning, non-monotonic rheological properties, injecting the treatment fluid into the subterranean formation, and inducing shear rate softening phase transition in the treatment fluid. The non-monotonic rheology properties can be such that in the relationship between shear stress (?) versus strain rate ({dot over (?)}), where {dot over (?)}1<{dot over (?)}2<{dot over (?)}3<{dot over (?)}4, the shear stress values are ?1<?2?3??4, and ?3<?2 The method can heterogeneously deposit proppant or solid acid in a fracture. A system to fracture a subterranean formation includes the fracturing fluid, a wellbore to inject the fracturing fluid to propagate a fracture in the formation, and a rate controller to inject the fracturing fluid into the subterranean formation at a minimum volumetric rate to provide a shear stress at an inlet to the fracture that exceeds ?2.

Abstract: The present invention relates to improved low-quality particulates and methods of making such improved particulates. A method of treating a portion of a subterranean formation, comprising providing a slurry comprising a treatment fluid and low-quality particulates at least partially coated with an aqueous tackifying composition, wherein the aqueous tackifying composition comprises an aqueous tackifier compound and an aqueous liquid; introducing the slurry into a subterranean formation; and, depositing the coated, low-quality particulates into the portion of this subterranean formation. A method of improving particulates, comprising at least partially coating low-quality particulates with an aqueous tackifying composition, wherein the aqueous tackifying composition comprises an aqueous tackifier compound and an aqueous liquid.

Abstract: A zirconium cross-linking agent produced by a process which comprises contacting a zirconium triethanolamine complex with a mixture of polyols, which mixture comprises a hydroxyalkylated diamine and a hydrocarbon polyol. There is further provided a cross-linking composition which comprises (a) an aqueous liquid, (b) a cross-linkable organic polymer, and (c) a solution of a zirconium cross-linking agent which is produced by a process which comprises contacting a zirconium triethanolamine complex having a molar ratio of 1:2 to 1:5 of zirconium to triethanolamine with a mixture of polyols, which mixture comprises a hydroxyalkylated diamine and a hydrocarbon polyol wherein the molar ratio of zirconium to hydroxyalkylated diamine is 1:0.5 to 1:1 and the molar ratio of zirconium to hydrocarbon polyol is 1:0.5 to 1:1.5. The composition can be used in oil field applications for hydraulic fracturing and plugging of permeable zones and leaks in subterranean formations.

Abstract: A system includes a wellbore in fluid communication with a formation of interest and a fracturing slurry include a carrier fluid with a low amount of a viscosifier, an amount of proppant including a first average particle size between about 200 and 2000 ?m, an amount particulates including a second average particle size between about three and ten times smaller than the first average particle size, and a third amount of particulates having a third average particle size smaller than the second average particle size. A sum of all of the particulates in the fracturing slurry exceed about 16 pounds per gallon of the carrier fluid. They system further includes a pumping device that creates a propped fracture in the formation of interest with the fracturing slurry, and a removal agent that removes the second amount of particulates and/or the third amount of particulates from the propped fracture.

Abstract: Methods are providing, including methods comprising providing a liner disposed within a well bore that penetrates a subterranean formation, such that the well bore comprises an annular space between the exterior surface of the liner and the well bore wall; providing a jetting tool disposed within the liner; introducing a stimulation fluid to a treatment interval of the well bore via the jetting tool, such that the stimulation fluid is introduced with sufficient pressure to create or enhance a plurality of perforations in the liner in the treatment interval; introducing a proppant slurry comprising a plurality of resin-coated particulates to the treatment interval of the well bore; and allowing the resin-coated particulates to fill at least a portion of the liner in the treatment interval and at least a portion of the annular space in the treatment interval.

Abstract: Methods and compositions for consolidating particulate matter in a subterranean formation are provided. In one embodiment, a method of treating a subterranean formation includes coating a curable adhesive composition comprising a silane coupling agent and a polymer having a reactive silicon end group onto proppant material; suspending the coated proppant material in a carrier fluid to form a proppant slurry; introducing the proppant slurry into a subterranean formation; and allowing the curable adhesive composition to at least partially consolidate the proppant material in the subterranean formation.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert degradable polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert degradable polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert degradable polymer may or may not substantially enter formation pores.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores.

Abstract: A method for well treatment by forming a temporary plug in a fracture, a perforation, a wellbore, or more than one of these locations, in a well penetrating a subterranean formation is provided, in which the method of well treatment includes: injecting a slurry comprising a degradable material, allowing the degradable material to form a plug in a perforation, a fracture, or a wellbore in a well penetrating a formation; performing a downhole operation; and allowing the degradable material to degrade after a selected time such that the plug disappears.

Abstract: Methods of hydraulically fracturing subterranean coal seams and formations resulting in improved permeability to stimulate Coalbed Methane. In one method, the coal seam is fractured using a proppant-containing fracturing fluid in alternating stages with an aqueous base solution that etches the fracture faces of the coal thereby creating channels for fluid flow. In another method, the coal seam is fractured using a fracturing fluid without propping agents in alternating stages with an aqueous base solution that is pumped at a pressure sufficient to maintain the fractures in an open position thereby etching the fracture faces to create channels for fluid flow. In yet another embodiment, a base solution is injected into the formation at a pressure sufficient to create fractures therein and simultaneously etch the faces of the open fractures to thereby form channels in the faces for increased fluid flow.

Abstract: The present invention is directed to a method of isolating hydrajet stimulated zones from subsequent well operations. The method includes the step of drilling a wellbore into the subterranean formation of interest. Next, the wellbore may or may not be cased depending upon a number of factors including the nature and structure of the subterranean formation. Next, the casing, if one is installed, and wellbore are perforated using a high pressure fluid being ejected from a hydrajetting tool. A first zone of the subterranean formation is then fractured and stimulated. Next, the first zone is temporarily plugged or partially sealed by installing an isolation fluid into the wellbore adjacent to the one or more fractures and/or in the openings thereof, so that subsequent zones can be fractured and additional well operations can be performed.

Abstract: Methods that comprise selecting proppant for use in a fracturing fluid based on one or more factors, wherein the one or more factors comprise an interaction between the proppant and the fracturing fluid. Methods that comprise designing a treatment fluid that comprises a gelled base fluid and a particulate based on one or more factors, wherein the one or more factors comprise an interaction between the particulate and the gelled base fluid.

Abstract: Methods for setting particulate plugs in at least partially horizontal sections of well bores are disclosed. In one embodiment, a method comprises the step of selecting a deposition location for a particulate plug within the at least partially horizontal section of the well bore. The method further comprises the step of providing a pumping conduit capable of delivering slurries to the deposition location. The method further comprises the step of pumping a first slurry through the pumping conduit to the deposition location such that a velocity of the first slurry in the well bore at the deposition location is less than or equal to the critical velocity of the first slurry in the well bore at the deposition location.

Abstract: A composite proppant having a proppant substrate such as a porous ceramic or silica sand coated with magnetic particles and a method of propping a subterranean formation using a composition consisting essentially of the composite proppant.

Abstract: An apparatus for supplying proppant is disclosed, comprising a vessel and a level monitor. The vessel has an interior containing a mixture of proppant and liquid, an inlet for supplying proppant to the interior, and an outlet for supplying the mixture of proppant and liquid from the interior of the vessel. The level monitor is associated with the vessel for monitoring at least a level of liquid and has a discriminator for discriminating between the level of liquid and a level of proppant in the mixture of proppant and liquid. A method of supplying proppant is also disclosed. A vessel is provided at least partially filled with a mixture of proppant and liquid and having a level of liquid and a level of proppant. The level of liquid in the mixture of proppant and liquid is monitored. The mixture of proppant and liquid is supplied from the vessel through an outlet in the vessel.

Abstract: A production tubing comprising a liner is placed downhole in a wellbore. A fluid pill containing proppant is squeezed into the annulus between the formation and liner, thereby packing the proppant into the annulus, effectively isolating the annulus. The packed proppant is permeable to liquids but impermeable to fracturing proppants. After isolation of the annulus, the wellbore may be perforated using a resettable perforation assembly. Once perforating is complete, the wellbore is fractured. The presence of the packed proppant in the annulus generates resistance to the flow of fracturing fluid along the annulus, forcing the fracture to propagate down the perforation tunnels, while also allowing subsequent production fluids to be produced along the annulus.

Abstract: An improved method for building a plug in a horizontal wellbore using a fluid pill pumped into the wellbore at the end of a fracturing treatment. The fluid pill includes a high concentration of an ultra lightweight proppant, such as a neutrally buoyant proppant or an ultra lightweight proppant mixture. The fluid pill is pumped down the wellbore until it almost reaches fractures within a zone of interest. The pumping is then ceased or reduced, allowing the fractures to partially close. The ultra lightweight proppant remains suspended within the fluid pill while stationary. The pumping is then resumed at a very slow rate or as a short pump burst, thus causing the proppant in the fluid pill to bridge off until a bridge plug is formed.

Abstract: A method of treating a shale-containing subterranean formation penetrated by a wellbore is accomplished by forming a carbon dioxide treatment fluid having a viscosity of less than about 10 mPa-s at a shear rate of about 100 s?1. The carbon dioxide treatment fluid is introduced into the formation through the wellbore at a pressure above the fracture pressure of the formation. In certain embodiments, the treatment fluid may be comprised of from about 90% to 100% by weight carbon dioxide and may contain a proppant. A method of treating hydrocarbon-bearing, shale-containing subterranean formation penetrated by a wellbore may also be carried out by forming a carbon dioxide treatment fluid and introducing the carbon dioxide treatment fluid into the formation through the wellbore at a pressure above the fracture pressure of the formation. The formation being treated may have a permeability of less than 1 mD.

Abstract: A method and apparatus for ratcheting a stimulation tool in a well in which the stimulation tool is movable from a first radial position to a second radial position without moving the tool string.

Abstract: Particulate material used for proppant flowback control from the fracture, where the material is a polymer which increases its hardness under downhole conditions.

Abstract: A method of mitigating proppant settling in a hydraulic fracture in order to better suspend the proppant as well as ensure a more uniform pack, by mixing a pre-determined volume percent of low density additive, such as glass beads or other suitable material, such as polylactic acid particles, into the fracturing slurry along with the standard high-density proppant, it is anticipated that density gradients can be induced inside the fracture. Upward movement of low density additive due to them having density lower than the carrier fluid will interfere with downward movement of high-density proppant and vice versa. This mutual interference between the two proppants confined in the narrow fracture will significantly hinder the settling/segregation of the high-density proppant. The low density material has a specific gravity of about 0.3, particle size distribution similar to that of standard proppant, and sufficient mechanical strength to survive fracture closure stress.