Abstract: Methods and compositions that include a method of treating a subterranean formation comprising the steps of providing a carrier fluid comprising degradable balls that comprise a carboxylic acid, a fatty alcohol, a fatty acid salt, a fatty ester, a fatty acid salt, or a combination thereof, and introducing the carrier fluid to the subterranean formation during a treatment.

Abstract: Methods comprising conveying a downhole tool within a wellbore penetrating a subterranean formation, wherein the downhole tool comprises a first pump and a second pump, and wherein at least one operational capability of the first and second pumps is substantially different. A fracture is initiated in the subterranean formation by pumping fluid into the formation using the first pump. The fracture is propagated in the subterranean formation by pumping fluid into the formation using the second pump.

Abstract: Using stabilized fluids in multistage well treatment is disclosed. Also disclosed are methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to a stabilized treatment slurry.

Abstract: A method of cementing a wellbore, comprising delivering a diversion and movable isolation tool into the wellbore and thereby at least partially isolating a first wellbore volume from a second wellbore volume, the second wellbore volume being uphole relative to the first wellbore volume, passing fluid through the diversion and movable isolation tool into the first wellbore volume, substantially discontinuing the passing of fluid through the diversion and movable isolation tool into the first wellbore volume, passing fluid through the diversion and movable isolation tool into the second wellbore volume. A diversion and movable isolation tool for a wellbore, comprising a body comprising selectively actuated radial flow ports, and a fluid isolation assembly, comprising one or more segments, each segment comprising a central ring and at least one tab extending from the central ring.

Abstract: The method disclosed herein includes the introduction of proppant-free stage and a proppant laden stage into the wellbore and/or subterranean formation. The method increases the effective fracture width and enhances fracture conductivity within the formation. Either the proppant-free stage or the proppant laden stage contains a breaker. The other stage contains a viscosifying polymer or viscoelastic surfactant to which the breaker has affinity. The proppant-free stage may be introduced prior to introduction of the proppant laden stage into the wellbore and/or formation. Alternatively, the proppant laden stage may be introduced into the wellbore and/or formation prior to introduction of the proppant-free stage.

Abstract: Methods of treating a subterranean formation including providing a wellbore in a subterranean formation having at least one fracture; providing an expandable cementitious material; introducing the expandable cementitious material into the at least one fracture in the subterranean formation; curing the expandable cementitious material so as to form a cement pack, wherein the curing of the expandable cementitious material expands the expandable cementitious material such that at least one microfracture is created within the at least one fracture in the subterranean formation; and acid-fracturing the at least one fracture in the subterranean formation.

Abstract: Methods of treating a subterranean formation having at least one fracture including providing a cement slurry comprising an expandable cementitious material and a breakable foamed carrier fluid, wherein the expandable cementitious material is capable of consolidating to form a plurality of expandable cementitious material aggregates and wherein the breakable foamed carrier fluid is capable of coating and isolating the expandable cementitious material aggregates; introducing the cement slurry into the fracture; curing the expandable cementitious material aggregates so as to form a cement pillar within the fracture in the subterranean formation, wherein the curing of the expandable cementitious material aggregates expands the expandable cementitious material aggregates such that at least one microfracture is created within the fracture; breaking the breakable foamed carrier fluid; removing the broken breakable foamed carrier fluid from the subterranean formation; and acid-fracturing the at least one fracture in

Abstract: Methods of treating a wellbore in a subterranean formation having a top portion and a bottom portion, and a middle portion therebetween. The method includes providing a jetting fluid; providing a cement slurry; and providing a breakable gel fluid. Then introducing the jetting fluid into the bottom portion of the wellbore to create or enhance a bottom portion fracture; introducing the jetting fluid into the top portion of the wellbore to create or enhance a top portion fracture; introducing the cement slurry into the top portion fracture; introducing the cement slurry into the bottom portion fracture; and introducing the breakable gel fluid into the wellbore so as to prevent the expandable cementitious material from migrating out of the top portion fracture and bottom portion fracture. The expandable cementitious material is cured so as to form a cement pack, the breakable gel fluid is broken and removed from the subterranean formation.

Abstract: The present invention provides a method for selectively sealing a thief zone in a hydrocarbon reservoir located in a calcium-rich formation and penetrated by a borehole comprising injecting into the thief zone a sealing fluid comprising a mixture of and hydronium ions (H+) and a source of sulfate ions (SO42?) which mixture can provide precipitation of a designated calcium sulfate compound.

Abstract: A well treatment fluid containing borated galactomannan may be used to isolate a productive zone in a well having multiple productive zones. The fluid is particularly useful in treatment of wells containing a mechanical zonal isolation system in the productive zone of interest. The fluid is pumped into the well in a substantially non-hydrated form. The well treatment fluid is therefore highly effective in preferentially sealing or blocking productive zones in the formation since delayed hydration of the fluid may be controlled for up to several hours. The seal may be degraded and a productive zone subjected to re-fracturing by introducing a viscosity reducing agent into the well.

Abstract: Apparatus and methods for managing cementing operations are provided. An example method includes connecting a cementing adapter atop a casing head itself positioned atop a surface casing landed within a conductor pipe, connecting a drilling adapter atop the cementing adapter, connecting a blowout preventer to the drilling adapter, and drilling for and running production casing. The method also includes positioning a casing hanger at least partially within a bore of the cementing adapter to be immobilized therein to retain back pressure of cement within an annulus located between the production casing and the surface casing, cementing the production casing within the surface casing, and removing the drilling adapter and blowout preventer after running the cement, but typically prior to cement bonding.

Abstract: Methods are circulated degradable material assisted diversion (CMAD) for well treatment in completed wells. A slurry of solid degradable material is circulated in the well with return of excess slurry, a plug of the degradable material is formed, a downhole operation is performed around the plug diverter, and the plug is then degraded for removal. Degradation triggers can be temperature or chemical reactants, with optional accelerators or retarders to provide the desired timing for plug removal. In multilayer formation CMAD fracturing, the plug isolates a completed fracture while additional layers are sequentially fractured and plugged, and then the plugs are removed for flowback from the fractured layers.

Abstract: Methods are included that are useful in treating subterranean formations and, more particularly, to minimizing particulate migration over long intervals in subterranean well bores that may be horizontal, vertical, deviated, or otherwise nonlinear. In one embodiment, a method is presented comprising: providing a well bore comprising an open hole section of about 30 feet or more that comprises an open hole section with a filter cake neighboring at least a portion of a reservoir; allowing the integrity of at least a portion of the filter cake to become compromised; and treating at least a portion of the open hole section with a consolidating agent system in a single stage operation so as to at least partially reduce particulate migration in the open hole section.

Abstract: Fracturing operations can be problematic in completed wellbores containing at least one existing fracture, since it can be difficult to seal an existing fracture and initiate a new fracture within a reasonable timeframe due to the presence of particulate materials in the wellbore. Methods for fracturing a completed wellbore can comprise introducing a treatment fluid comprising a plurality of degradable sealing particulates into a completed wellbore penetrating a subterranean formation having an existing fracture therein; sealing the existing fracture with at least a portion of the degradable sealing particulates, thereby forming a degradable particulate seal; after sealing, allowing any degradable sealing particulates remaining in the treatment fluid to degrade, such that the treatment fluid becomes substantially particulate free; and after the treatment fluid becomes substantially particulate free, fracturing the subterranean formation so as to introduce at least one new fracture therein.

Abstract: Methods for remediating a subterranean formation can comprise: introducing a first remedial fluid into a first portion of a subterranean formation, wherein the first remedial fluid comprises a base fluid and a viscosifying agent; and allowing the first remedial fluid to divert at least a portion of a second remedial fluid that comprises an oxidizer to a second portion of the subterranean formation; wherein the viscosifying agent comprises at least one viscosifying agent selected from the group consisting of a gelling agent, an emulsifier, or a gas in combination with a foaming agent; and wherein the gelling agent, if present, comprises at least one polymer selected from the group consisting of xanthan, diutans, wellans, succinoglycan, clarified biopolymers, scleroglycan, combinations thereof, and derivatives thereof.

Abstract: A method for diverting fluids across a perforation tunnel in high-rate water pack operations may include providing a wellbore extending into a subterranean formation, wherein a perforation tunnel provides a fluid connection between the wellbore and the subterranean formation; providing a diverting particulate that comprises a degradable plasticized polymer coating on a particulate; placing the diverting particulate into the perforation tunnel, wherein the step of placing the diverting particulate forms a particulate pack within the subterranean formation and the perforation tunnel; allowing the degradable plasticized polymer coating to deform and fill the interstitial spaces within the particulate pack in the perforation tunnel such that the fluid conductivity between the wellbore and the subterranean formation is substantially blocked; and allowing the plasticized polymer coating to degrade over time thereby substantially restoring the fluid conductivity between the wellbore and the subterranean formation.

Abstract: A method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided. The method includes the steps of: According to an embodiment, a method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided, the method including the steps of: (a) forming a treatment fluid comprising: (i) water; (ii) a water-soluble polymer having at least one functional group that can be crosslinked with aluminum(III); and (iii) a water-soluble aluminum carboxylate; wherein the pH of the treatment fluid is less than 1; (b) introducing the treatment fluid through the wellbore into the zone; and (c) allowing time for the strong acid in the treatment fluid to spend in the formation such that the pH of the fluid increases sufficiently for the aluminum of the aluminum carboxylate to crosslink the polymer.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a first wellbore servicing fluid comprising a self-degrading diverter material into the wellbore wherein the self-degrading diverter materials comprises (i) a diverting material and (ii) a degradation accelerator; allowing the self-degrading diverter material to form a diverter plug at a first location in the wellbore or subterranean formation; diverting the flow of a second wellbore servicing fluid to a second location in the wellbore or subterranean formation; and removing the diverter plug, wherein the first and second wellbore servicing fluids may be the same or different.

Abstract: A method of degassing a coal seam by directionally drilling a borehole in a rock formation that is adjacent the coal seam, or between two different coal seams. The borehole is then pressurised to fracture the adjacent coal seam(s) to enhance the permeability thereof and allow fluids to flow from the coal seam to the borehole and be extracted from the coal seam.

Abstract: In order to overcome the need to remove each packer after a plug and perforate operation in order to produce a well it is desirable to utilize an erodible packer that may allow one way flow. An erodible packer may be constructed of a material such as polyglycolic acid as a binder. The same packer may also allow one way flow past the packer, such as flow from the casing below the packer to the casing above the packer. The packer may erode upon the expiration of a predetermined period of time or upon exposure to an activating agent.

Abstract: The external surface of a tubular body such as well casing is coated with a substance that, upon exposure to cement, is unstable and degrades. After installation in a subterranean well and subsequent cementation, the coating degrades and forms a gap between the external surface of the tubular body and the cement sheath. Forming the gap is useful for obtaining optimal stimulation during the hydraulic fracturing of unconventional shale-gas formations.

Abstract: Methods of fracturing a well can include the steps of: (A) obtaining a fracturing job design having at least one treatment interval; (B) running a tubular string into the treatment interval; (C) before or after the step of running, forming one or more tubular string openings in the tubular string, wherein after the step of running, the one or more tubular string openings are positioned in the treatment interval; (D) except for the axial passageway of the tubular string, blocking at least 86% of the nominal cross-sectional area of the treatment interval that is between one of the ends of the treatment interval and the axially closest of the one or more tubular string openings, and, except for the axial passageway of the tubular string, leaving unblocked at least 4% of the nominal cross-sectional area of the treatment interval; and (E) pumping a fracturing fluid through the one or more tubular string openings at a rate and pressure sufficient to initiate at least one fracture in the subterranean formation surro

Abstract: Treating a subterranean formation includes injecting a magnetically permeable material into the formation and energizing the magnetically permeable material using electromagnetic radiation. The magnetically permeable material reacts to the electromagnetic radiation by producing heat. In some embodiments, a fracturing fluid is made magnetically permeable, injected into the formation to fracture the formation, and heated in response to electromagnetic radiation applied to the magnetically permeable material. In some embodiments, electromagnetically heated material is caused to explode. In some embodiments, the magnetically permeable material is tracked or monitored for fluid or fracture propagation. A system includes a fluid treatment tool disposed on a tubing string for injecting magnetically permeable material and an electromagnetic wave generator disposed on the tubing string proximate the fluid treatment apparatus for applying electromagnetic radiation to the magnetically permeable material.

Abstract: A silicate gel composition that is useful for sealing the face of a fracture of a formation. A method of sealing a face of a fracture of a formation with the silicate gel composition and diverting an acid treatment fluid.

Abstract: An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology effected with addition of a fatty dimer diamine additive in the presence of little or no lime. The drilling fluids of the present invention exhibit similar yield points and gel strengths at temperatures ranging from about 40° F. to about 375° F. or higher and at pressures ranging from about 0 psi to about 13500 psi.

Abstract: A stage tool for reverse annular cementing a wellbore, comprising: a main body including a tubular wall with an outer surface and a longitudinal bore extending from a top end to a bottom end; a fluid port through the tubular wall providing fluidic access between the longitudinal bore and the outer surface; and a valve for controlling flow through the fluid port between the outer surface and the inner bore, the valve including a closure for the fluid port and a check valve for permitting one way flow through the fluid port in a direction from the outer surface to the inner bore, the check valve being normally inactive and only acting on fluid flows through the fluid port when activated. The stage tool may be run in closed and opened for cementing by hydraulic actuation of the valve. After sufficient cement has been introduced to the annulus, the stage tool fluid port can be closed to hold the cement in the annulus.

Abstract: A method of servicing a wellbore comprising preparing a composition comprising a calcium aluminate cement, water, and a fluid loss additive wherein the fluid loss additive comprises an acid gelling polymer, placing the composition in the wellbore, and allowing the composition to set. A method of servicing a wellbore comprising placing into a wellbore having a bottom hole static temperature of greater than about 50° F. and/or a pH of from about 3 to about 9 a cement slurry comprising a calcium aluminate cement having an aluminum oxide content of greater than about 60 wt. % based on the total weight of the calcium aluminate cement and an acid-gelling polymer wherein the cement slurry has a fluid loss at 10 cc/10 min. to about 600 cc/30 min.

Abstract: Methods of controlling fluid loss, providing fluid diversion, or plugging a portion of a well bore using a treatment fluid including relatively insoluble borate material particulates that are placed into a subterranean formation to provide the desired action and then degrade over time in the subterranean formation in the presence of an aqueous fluid such as water.

Abstract: A method of well treatment includes establishing fluid connectivity between a wellbore and at least one target zone for treatment within a subterranean formation. The method includes injecting a treatment composition into the wellbore. The method includes contacting a subterranean formation with the treatment composition, providing a diversion agent to a desired interval in the wellbore and measuring a wellbore parameter while performing at least one of the contacting the target zone and the providing the diversion agent.

Abstract: A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. An activator is then delivered to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process.

Abstract: A method of cementing a liner string into a wellbore includes deploying a liner string into a wellbore; pumping cement slurry into a workstring; and pumping a dart through the workstring, thereby driving the cement slurry into the liner string. The dart engages a first wiper plug and releases the first wiper plug from the workstring. The dart and engaged first wiper plug drive the cement slurry through the liner string and into an annulus formed between the liner string and the wellbore. The dart and engaged first wiper plug land onto a first fracture valve. The dart releases a first seat into the first wiper plug. The dart engages a second wiper plug connected to the first fracture valve and releases the second wiper plug from the first fracture valve.

Abstract: Systems and methods for maximizing energy recovery from a subterranean formation are herein disclosed. According to one embodiment, a selected subterranean open-hole interval is isolated and at least one fracture is stimulated in the isolated subterranean open-hole interval.

Abstract: A well treatment fluid containing borated galactomannan may be used to isolate a productive zone in a well having multiple productive zones. The fluid is particularly useful in treatment of wells containing a mechanical zonal isolation system in the productive zone of interest. The fluid is pumped into the well in a substantially non-hydrated form. The well treatment fluid is therefore highly effective in preferentially sealing or blocking productive zones in the formation since delayed hydration of the fluid may be controlled for up to several hours.

Abstract: A deformation system, including a deformable member and a tool operatively arranged to deform the member due to actuation of the tool from a first set of dimensions at which the deformable member is positionable with respect to a structure to a second set of dimensions at which the deformable member engages with the structure. The tool at least partially comprises a disintegrable material responsive to a selected fluid. A method of operating a deformation system is also included.

Abstract: A method of treating a subterranean formation may include preparing a mortar slurry, injecting the mortar slurry into the subterranean formation at a pressure sufficient to create a fracture in the subterranean formation, and allowing the mortar slurry to set, forming a mortar in the fracture. The mortar slurry may be designed to form a pervious mortar, to crack under fracture closure pressure, or both.

Abstract: An assembly and process for fracturing, stimulating and producing a wellbore having a plurality of oil or gas producing zones is provided comprising introducing into the well the pumpable seat assembly comprising a generally cylindrical tube having an outer diameter and an inner diameter with an upper end forming a ball seat; setting the pumpable seat assembly below an oil or gas producing zone to be produced; introducing a dissolvable ball into the well, said dissolvable ball having a sufficiently large enough outer circumference so that it can sit on the ball seat and temporarily restrict a flow of fluids to the portion of the wellbore located below the pumpable seat assembly; and fracturing the oil and gas producing zone to stimulate oil or gas production; whereby the biodegradable ball is configured to dissolve within a predetermined period of time so that when it dissolves any oil or gas produced from zones below the pumpable seat assembly can flow through the cylindrical tube.

Abstract: A system is provided that is conducive to multi-stage stimulation in a near-continuous fashion. That is, unlike conventional stimulation systems, embodiments herein may operate without the requirement of traditional plug-setting, perforating and fracturing interventions on a zone by zone basis for a cemented completion. Rather, the system is outfitted with frac sleeves that may be shifted open to expose the bore to the formation while simultaneously achieving a seal through a ball drop technique. Once more, this manner of operation is rendered practical by the sleeve being of a passable configuration such that cementing of the casing is not impeded.

Abstract: A hydraulic fracturing method includes injecting a fluid containing a transitory binder and filler into a substantially horizontal well casing without any placement apparatus present in the substantially horizontal well casing, the filler containing particles of a solid material. The transitory binder and filler are placed over first perforations in the well casing. The method includes opening second perforations through the well casing, injecting additional fracturing fluid through the substantially horizontal well casing, and forming a plug over and through the first perforations with the transitory binder and filler.

Abstract: The invention provides economically effective methods for hydraulic fracturing a subterranean formation that ensure improvement of the hydraulic fracture conductivity because of forming strong proppant clusters uniformly placed in the fracture throughout its length. One of these methods comprises: a first stage comprising injection of fracturing fluid into a borehole, the fluid containing thickeners to create a fracture in the formation; and a second stage comprising introduction of proppant into the injected fracturing fluid to prevent closure of the created fracture, and further, comprising introducing an agent into the fracturing fluid to provide formation of proppant clusters in the created fracture and channels for flowing formation fluids.

Abstract: A method includes providing a treatment fluid that is a viscous fluid. The viscous fluid may be greater than 0.01 Pa-s, greater than 0.1 Pa-s, and/or a cross-linked polymer based fluid. The method further includes determining a fines migration composition soluble in an aqueous phase of the treatment fluid that is compatible with the treatment fluid, and that interacts to secure fines in an earth formation intersecting a wellbore within a fines reaction time. The method further includes adding an amount of the fines migration composition to the treatment fluid, and treating the earth formation with the treatment fluid. The method includes leaking off a portion of the treatment fluid into the earth formation, and providing a residence time of the leaked off portion of the treatment fluid in the earth formation, where the residence time meets or exceeds the fines reaction time.

Abstract: The invention provides a method comprising providing a composition comprising a pH trigger and a polymer able to be hydrated in a defined pH zone; injecting the composition with a pH outside the defined pH zone; triggering the pH trigger to adjust the pH of the composition within the defined pH zone; and allowing viscosity of the composition to increase and form a plug.

Abstract: System, devices, and methods are described relating to the treatment (e.g., perforating, fracturing, foam stimulation, acid treatment, cement treatment, etc.) of well-bores (e.g., cased oil and/or gas wells). In at least one example, a method is provided for treatment of a region in a well, the method comprising: positioning, in a well-bore, a packer above the region of the well-bore, fixing, below the region, an expansion packer, treating the region, the treatment fixing the packer, moving the expansion packer, and moving the packer after the moving of the expansion packer.

Abstract: An array of plugging devices are pumped sequentially from the surface through a liner, that typically becomes horizontal in nature, where each plugging device is anchorable at a specified position along the length of the liner. When the plugging device is anchored, a cluster of perforations is generated above the plugging device where the perforations may be created by detonation of a perforating gun attached to the top side of the plugging device or the perforations may be created by shifting of a sleeve that is anchored to the plugging device. The plugging device may be a cup plug where the cup is similar to a swab cup and when pump pressure is applied to the cup, a force is generated to make the cup move through the liner. When anchored, the cup also directs frac fluids through the perforations to treat the well formation.

Abstract: Compositions including relatively low reactivity acids and having a pH of from about 2 to about 5, mixed with viscoelastic surfactants (VESs) and internal breakers may serve as fluids, in a non-limiting embodiment as drilling fluids, to open underground hydrocarbon reservoirs with carbonate contents of 10 wt % or above. The fluids initially have low viscosities. After the fluid flows out of the drill bit, the acids react with carbonates in the formation thereby increasing the pH of the fluids causing the VES to gel the fluid at the bottom of the hole and within the formation rock. Even when the subterranean formation contains naturally-occurring fractures, the viscosified fluid will reduce fluid loss into the formation. After drilling through the targeted formation, internal breakers in the viscosified fluids will break down the fluids to permit their removal, and production of the well with very little or no near well bore damage.

Abstract: A system for forming a subterranean oriented fissure in a target zone by utilizing a connection between two well bores and a flexible linear cutting device, such as a segmented diamond wire saw, to form the fissure beginning at the connection of the well bores and extending along a specified the length of the well bores.

Abstract: A one-way flowable anchoring system includes a plurality of same anchors that are sealedly fixedly engagable within a structure and each of the plurality of same anchors has a flow bore longitudinally therethrough with a first seat and a second seat on opposing ends thereof The system also has a plug positionable within the structure between two of the plurality of same anchors positioned longitudinally adjacent one another.

Abstract: Disclosed herein are an acid emulsion fluid for use in sealing target portions of a hydrocarbon producing formation penetrated by a wellbore and the method of use thereof for fluid loss control.

Abstract: A pressure actuation enabling method includes plugging a passage that fluidically connects an inside with an outside of a tubular with a plug, building differential pressure across the plug, actuating an actuator with the differential pressure and removing the plug.

Abstract: The method of the present invention deploys CEM into the existing perforations to seal them and then using a BHA that isolates a portion of the wellbore to deliver a material that removes the CEM at a predetermined rate so that the BHA can be used to refracture the recently opened perforation. Additional new perforations can be made and fractured during the process.

Abstract: A method of permeating and infusing a formation around the borehole with wax by heating a formation surrounding a borehole and pumping molten wax into the formation, wherein the molten wax flows into and fills voids the formation without disrupting the formation is described. Also, a method of permeating and infusing a formation around the borehole with wax by heating a formation surrounding a borehole, pumping molten wax into the borehole, heating and circulating the molten wax vertically within the borehole for an extended period using a heater and pump attached to a circulation pipe extended to the bottom of a zone of the borehole to be heated, and recovering molten wax from the borehole by displacing it back to the surface with another material of different density is described.