Abstract: Methods for treating wellbores using fluids containing a sphingan heteropolysaccharide which contributes viscosity stability and a decrease in friction pressure. Some methods are clean-out operations using recyclable-viscosity fluids containing at least a sphingan heteropolysaccharide and an optional salt. Others include methods of pumping fluids incorporating sphingan heteropolysaccharides to reduce pumping frictional pressure.

Abstract: A method of controlling or arresting the rate of depolymerization of a polymer composition during a biocide treatment by controlling the pH of the composition, and use of such methods in oilfield applications.

Abstract: Treatments fluids relating to the hydrolysis of water-hydrolysable materials are provided. In one embodiment, provided is a treatment fluid that comprises an aqueous liquid, a water-miscible solvent, and a water-hydrolysable material. Also provided is a hydrolysis retarder composition that comprises an aqueous liquid and a water-miscible solvent.

Abstract: A pill for wellbore operations, that includes a base fluid; and at least two polymers that interact to form a gelatinous structure characterized as isolating and controllably transmitting hydrostatic pressure between a first wellbore fluid above the pill in a wellbore and a second wellbore fluid below the pill in the wellbore is disclosed.

Abstract: A thermal insulating packer fluid contains at least one water superabsorbent polymer and optionally water and/or brine, and a viscosifying polymer. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is sufficient to reduce the convection flow velocity within the annulus.

Abstract: Embodiments of this invention relate to compositions and methods of treating a subterranean formation penetrated by a well bore including introducing a Theological polymer into a subterranean formation, introducing a partitioning agent into a subterranean formation and forming a heterogeneous mixture comprising a dispersed Theological polymer-rich phase and a partitioning agent-rich phase, wherein the viscosity of the mixture is lower than the viscosity of the mixture when no partitioning agent is present.

Abstract: Methods which include hydrating a crystalline polymeric material in a first liquid medium, precipitating the polymeric material to form an amorphous polymeric material, and combining amorphous polymeric material with a second liquid medium to form a treatment fluid. Alternative methods include hydrating a crystalline polymeric material in a first liquid medium, precipitating the polymeric material to form a lower crystalline form of the polymeric material, and combining the lower crystalline form of polymeric material with a second liquid medium to form a treatment fluid.

Abstract: The present invention provides a method of forming a viscosified treatment fluid comprising: providing a treatment fluid that comprises water and a gelling agent; contacting the treatment fluid with a boronic acid crosslinking agent so as to form a crosslinked gelling agent, wherein the boronic acid crosslinking agent comprises a compound having the formula: The present invention also provides methods of crosslinking gelling agent molecules, methods of treating a subterranean formation, methods of reusing viscosified treatment fluids, methods of fracturing subterranean formations, and methods of placing a gravel pack in subterranean formations. The present invention also provides boronic acid crosslinking agents and viscosified treatment fluids that comprise crosslinked gelling agents, the crosslinked gelling agent being formed from a reaction comprising a gelling agent and a boronic acid crosslinking agent.

Abstract: A process for preparing a stable zirconium triethanolamine cross-linking agent comprises contacting a solution of a zirconium triethanolamine complex with water at a temperature of 50° C. to 90° C. at a mole ratio of triethanolamine:zirconium in the range of 3.5:5.5 and at a mole ratio of water:zirconium in the range of 20:1 to 1:1. The stable zirconium triethanolamine complex can be used in a cross-linking composition. Further disclosed are methods to use the composition in oil field applications for hydraulic fracturing and plugging of permeable zones and leaks in subterranean formations.

Abstract: A cross-linking composition comprises (a) an aqueous liquid, (b) a pH buffer, (c) a cross-linkable organic polymer, (d) a cross-linking agent which comprises an organic titanate, an organic zirconate, or combinations thereof, and (e) a delay agent which is a hydroxyalkylaminocarboxylic acid. The composition provides flexibility in rate of cross-linking and can be used over a wide range of pH. Further disclosed are methods to use the composition in oil field applications for hydraulic fracturing and plugging of permeable zones and leaks in subterranean formations.

Abstract: A process is provided to prepare solid borozirconate and solid borotitanate cross-linkers, which comprises contacting zirconium or titanium complex with alkanolamine at particular mole ratios of boron, zirconium or titanium and alkanolamine. Use of the cross-linkers in compositions for oil field applications such as hydraulic fracturing and plugging of permeable zones are also disclosed.

Abstract: Acidic treatment fluids used in industrial and/or subterranean operations, and more particularly, acidic treatment fluids comprising clarified xanthan gelling agents, and methods of use in industrial and/or subterranean operations, are provided. In one embodiment, the acidic treatment fluids comprise an aqueous base fluid, an acid, and a gelling agent comprising clarified xanthan.

Abstract: Acidic treatment fluids used in industrial and/or subterranean operations, and more particularly, acidic treatment fluids comprising clarified xanthan gelling agents, and methods of use in industrial and/or subterranean operations, are provided. In one embodiment, the methods comprise: providing an acidic treatment fluid that comprises an aqueous base fluid, an acid, and a gelling agent that comprises clarified xanthan; and introducing the acidic treatment fluid into a portion of a subterranean formation.

Abstract: The invention discloses a method of treating a wellbore by providing an aqueous mixture of a hydrated polysaccharide with a salt; adding to the mixture a cross-linking agent for cross-linking the hydrated polysaccharide, wherein the cross-linking agent comprises a zirconium compound, glutamic acid, and a polyol; pumping the aqueous mixture of the hydrated polysaccharide and the cross-linking agent into the wellbore; and cross-linking the hydrated polysaccharide.

Abstract: A method includes providing a wellbore treatment fluid having a divalent brine and an amount of polymer and lowering a pH value of the treatment fluid. The method further includes retaining the treatment fluid at the lower pH value until the polymer achieves a primary hydration value. The method further includes adding a cross-linking agent and a cross-linking delay agent to the treatment fluid. The cross-linking agent includes zirconium and/or titanium, and the cross-linking delay agent is a polyol. The method further includes performing a wellbore treatment with the treatment fluid.

Abstract: The disclosed compositions and methods utilize hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups. The polymers may exhibit physical association in solution at a specific temperature so as to provide a significant increase in viscosity at the specific temperature. The viscosity of such systems is substantially increased by the further inclusion of one or more hydrophilic components that may exhibit physical association in solution at one or more temperature trigger points and also associate with the one or more hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups.

Abstract: In one embodiment, the present invention provides a method of increasing the viscosity of a treatment fluid comprising the steps of: adding a networking agent to the treatment fluid, wherein the networking agent is represented by the formula: Y—X—[B(OR)2]n, wherein: Y is at least partially capable of forming a crosslink between a gelling agent molecule, a second networking agent, and/or a combination thereof; X is at least partially capable of preventing or inhibiting a reaction represented by the formula: ROH+R?B(OR)2?R?OH+B(OR)3; R and R? are a hydrogen, an alkyl group, an aryl group, or a combination thereof; and n is a positive integer greater than or equal to 1; allowing at least one crosslink to form between the networking agent and a gelling agent molecule, a second networking agent, and/or a combination thereof; and allowing the viscosity of the treatment fluid to increase.

Abstract: A method is provided for inhibiting scale in a hydrocarbon system, including the steps of: providing a hydrocarbon system; providing an aloe-derived scale inhibitor; and mixing the aloe-derived scale inhibitor with the hydrocarbon system in amounts effective to inhibit formation of scale. The scale inhibitor is an aloe vera gel/aloe sap mix dissolved in water at a concentration of between about 5 and about 50% wt/wt, which includes polysaccharides having a hydrocarbon chain structure having carboxyl and alcohol functional groups that interact with divalent ions.

Abstract: The present invention relates to methods and compositions for carrier fluids comprising water-absorbent fibers. One embodiment of the present invention provides a method of treating a portion of a subterranean formation, comprising providing a slurry wherein the slurry comprises a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry; and, introducing the slurry into the portion of the subterranean formation. Another embodiment of the present invention provides a slurry suitable for use in subterranean operations comprising a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry.

Abstract: Disclosed are stabilized aqueous polymer compositions containing A) a stabilizing amount of a least a sulfur dye or containing a stabilizing amount of a sulfur dye with a compound comprising a heterocyclic system containing nitrogen and sulphur as ring heteroatoms and B) at least one polymer comprising groups which are capable of complex formation with ions. The aqueous polymer compositions are stabilized against thermal or other degradation processes of the polymer by addition of component A) to allow their use even under harsh conditions.

Abstract: A well treatment fluid and method uses an organic peroxide. An activator embodiment can lower an effective concentration of the peroxide to break the fluid. A weight ratio of activator:organic peroxide can be at least about 1:20 in one well treatment fluid embodiment. A peroxyester breaker embodiment can be used in a well treatment fluid and method. A breaker delay agent embodiment can control the polymer break window in a well treatment fluid and method using an organic peroxide. A breaker package embodiment used in a well treatment fluid and method can include an organic peroxide and an amine breaker delay agent having the formula RR1NR2 wherein R, R1 and R2 are independently selected from hydrogen, alkyl, hydroxyalkyl, and combinations thereof.

Abstract: Methods of treating a subterranean formation are disclosed, using a fluid including an essentially metal-free organic crosslinker selected from amines, diamines, poly amines, polyamino polymers, alcohols, polyols, polyhydroxy polymers, hydroxyl amines, peptides and proteins, combined with a polysaccharide or cellulosic material having oxidized functional groups. The fluid is then introduced into a wellbore penetrating the formation to contact the formation. The polysaccharide or cellulosic material may have aldehyde groups as one example of an oxidized group, or any other suitable oxidized functional group. The polysaccharide or the cellulosic material may be oxidized using at least one of an enzymes, oxidizers, photooxidation, bacteria, catalyst, or other suitable technique. The fluid may also further include an inorganic crosslinker.

Abstract: A polyelectrolyte complex for the controlled release of an oil and gas field chemical selected from the group consisting of (a) a gel-forming or cross-linking agent, (b) a scale inhibitor, (c) a corrosion inhibitor, (d) an inhibitor of asphaltene or wax deposition, (e) a hydrogen sulfide scavenger, (f) a hydrate inhibitor, (g) a breaking agent, and a surfactant.

Abstract: This relates to a method and composition for forming and utilizing a fluid in the oilfield services industry including exposing a polyacid and/or polyacid derivative to a preparation method, introducing the prepared polyacid and/or polyacid derivative to a fluid to form a treatment fluid, and treating a subterranean formation and/or a wellbore with the treatment fluid, wherein the viscosity of the treatment fluid is not observably reduced by introducing the prepared polyacid and/or polyacid derivative to a treatment fluid. This also relates to a method and composition for use in the oil field services industry including a prepared polyacid and/or polyacid derivative, a fluid, and a viscosity control agent, wherein the viscosity of the composition is not observably lower than if the prepared polyacid and/or polyacid derivative were not present.

Abstract: Compositions and methods are given for delayed breaking of viscoelastic surfactant gels inside formation pores, particularly for use in hydraulic fracturing. Breaking inside formation pores is accomplished without mechanical intervention or use of a second fluid. Acidic internal breakers such as sulfuric acid and nitric acid are used. The break may be accelerated, for example with a free radical propagating species, or retarded, for example with an oxygen scavenger.

Abstract: Treating fluid compositions for use in hydrocarbon recovery operations from subterranean formations are described, as well as methods for their preparation and use. In particular, treating fluid compositions are described which comprise a liquid, a crosslinkable organic polymer material that is at least partially soluble in the liquid, a crosslinking agent that is capable of increasing the viscosity of the treating fluid by crosslinking the organic polymer material in the liquid, and a crosslinking modifier additive which can delay or accelerate the crosslinking of the treating fluid composition. Such compositions may be used in a variety of hydrocarbon recovery operations including fracturing operations, drilling operations, gravel packing operations, water control operations, and the like.

Abstract: The present invention relates to compositions for treating subterranean formations. A treatment fluid that comprises an aqueous liquid, and a degradable surfactant derived from a degradable polymer is provided. Also provided are emulsified treatment fluids and foamed treatment fluids that comprise degradable surfactants derived from degradable polymers.

Abstract: The invention discloses a well treatment composition for use in a subterranean formation comprising: a carrier fluid; and a viscoelastic surfactant being present in a concentration of less than about 1.5% by weight. Optionally, the fluid comprises a crosslinked polymer in a thickening amount in the carrier fluid. The invention also discloses a method to increase the viscosity of a fluid, the method comprising: providing a fluid comprising a thickening amount of a crosslinked polymer; adding a viscoelastic surfactant at a given concentration to the fluid; taking the fluid to a given temperature; defining a viscosity profile of the fluid depending of the concentration and the temperature; comparing said viscosity profile to a viscosity profile of the crosslinked polymer fluid alone; and defining an optimum concentration of the viscoelastic surfactant for each temperature.

Abstract: A fluid loss pill that includes a crosslinked polymer gel, a brine, and solid salt particles disposed in said gel is described. Further, a method for reducing fluid loss that includes pumping a selected amount of a fluid loss pill into a wellbore leading to an oil-condensate-, or gas-producing formation, the fluid loss pill including a crosslinked polymer gel, a brine, and solid salt particles disposed in said gel is described.

Abstract: The amount of crystallized salt in an oil and/or gas well may be minimized or reduced by use of a fructan, such as inulin, or a derivative as a salt block inhibitor. A preferred salt inhibitor is the salt of carboxyalkyl inulin such as a sodium salt of carboxymethyl inulin. The salt block inhibitor may be adsorbed onto a water-insoluble adsorbent.

Abstract: The invention relates to novel wellbore treatment methods and fluids using compositions formed from an aqueous medium, a regularly substituted hydrophilically functional polysaccharide having a degree of substitution from about 0.1 to about 0.5, wherein the percent of insoluble polysaccharide is about 10% or less, and a crosslinker. The wellbore treatment fluid is particularly useful for fracturing a subterranean formation penetrated by a wellbore.

Abstract: A thermal insulating fluid contains microspheres of hollow spherical particulates. The presence of the hollow spherical particles improves the thermal insulating properties of the fluid by imparting to the thermal insulating fluid a low heat transfer coefficient. The hollow particulates may be inorganic or organic in nature and include hollow spheres of glass, ceramics and plastics. The thermal insulating fluid is capable of controlling the heat transfer from a production tubing or transfer pipe to one or more surrounding annuli and the environment. In addition to reducing heat transfer in the producing well, heat transfer in the fluid produced from the well is also minimized.

Abstract: A non-aqueous, non-flammable Group IVB metal alkoxide crosslinker composition includes a non-aqueous, non-flammable Group IVB metal alkoxide, wherein the metal is chemically bonded to a glycol containing 4 or more carbons, to an alkoxy group containing 6 or more carbons, or a mixture of both. A fracturing fluid employed in the hydraulic fracturing of subterranean formations is formulated through mixture of the non-aqueous, non-flammable Group IVB metal alkoxide crosslinker composition with a polymer solution.

Abstract: A completion and workover fluid composition comprising, water and at least one rheology modifier and/or fluid loss control agent, and at least one other ingredient selected from the group consisting of inorganic salts, shale inhibitors, corrosion inhibitor, biocide, defoamers and finely divided solids particles (e.g., bentonite, attapulgite, sepiolite, calcium carbonate, etc.), depending upon the desired attributes, wherein the rheology modifier and/or the fluid loss control agent is an ethoxylated raw cotton linters or a modified ethoxylated raw cotton linters. The ethoxylated raw cotton linters provides comparable or better rheology and viscosity properties compared to high molecular weight commercial HECs made from purified cotton linters. These ethoxylated raw cotton linters derivatives are suitable for applications in oil-well servicing fluids, particularly to enhance functional properties of completion and workover fluids used during oil-well drilling operations.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant (16) 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. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant in the fracture, and later dissolving to leave the flow channels between the proppant pillars.

Abstract: Methods and compositions are provided that include a water-in-oil composition comprising an oil-based continuous phase and a discontinuous phase that comprises at least a plurality of hydrogel droplets and a method comprising providing a water-in-oil emulsion comprising an oil-based continuous phase and a discontinuous phase that comprises at least a plurality of hydrogel droplets; and placing the water-in-oil emulsion in a well bore penetrating a subterranean formation. Additional methods are also provided.

Abstract: Particulate compositions that comprise macro-particulates, and degradable particulates in an amount sufficient to reduce friction between the macro-particulates, the degradable particulates having a mean particle diameter of at least about 20 times smaller than the mean particle diameter of the macro-particulates are disclosed herein. Also disclosed are fluids that comprise a liquid component, and a particulate composition, the particulate composition comprising macro-particulates and degradable particulates having a mean particle diameter of at least about 20 times smaller than the mean particle diameter of the macro-particulates, wherein the degradable particulates are present in the particulate composition in an amount sufficient to reduce friction between the macro-particulates. Methods of using the particulate compositions and fluids are also disclosed.

Abstract: A method is given for the delayed breaking of a low pH fracturing fluid with acid-generating degradable elongated particles as a breaker for borate-crosslinked polymers. The shape, size, chemical composition and concentration of the elongated particles are used to control the period of delay before the polymer viscosity is broken.

Abstract: The invention provides a method for treating a subterranean formation penetrated by a wellbore, the method comprising the steps of formulating a treatment fluid and introducing the treatment fluid through the wellbore. The treatment fluid comprises water; diutan; and a sufficient amount of salt to increase the density of the treatment fluid to at least 8.5 lb/gal, wherein at least 50% by weight of the salt is selected from the group consisting of: bromide salts, non-bromide salts having a higher salting-in effect than bromide according to the Hofmeister series as measured by the salt's effect on the cloud point of poly(ethylene oxide) that has a molecular weight of 4×106, and any combination in any proportion thereof. The invention also provides a treatment fluid for use in a subterranean formation penetrated by a wellbore, the treatment fluid comprising: water; diutan; and a sufficient amount of salt to increase the density of the treatment fluid to at least 8.

Abstract: Methods comprising: providing a treatment fluid comprising: an aqueous base fluid and a gelling agent that comprises a nonnatural galactomannan; and placing the treatment fluid into the subterranean formation. Treatment fluids suitable for use in a subterranean treatment operation comprising an aqueous base fluid and a gelling agent that comprises a nonnatural galactomannan.

Abstract: A method is provided for producing a guar gum powder, the method comprising the steps of: (a) flaking undehusked guar splits; and (b) grinding the flaked, undehusked guar splits to obtain guar gum powder. According to another aspect of the invention, a method is provided for treating a subterranean formation penetrated by a wellbore, the method comprises the steps of: (a) forming a treatment fluid, wherein the treatment fluid comprises: (i) an aqueous fluid; and (ii) a guar gum powder comprising at least 70% by weight gum material and at least 15% by weight husk material; and (b) introducing the treatment fluid into the subterranean formation through the wellbore, According to yet another aspect of the invention, the product of the method for producing a guar gum powder is used in the method for treating a subterranean formation.

Abstract: A treatment fluid composition for treating a subterranean formation is formed from an aqueous fluid, a hydratable polymer and a polymer breaking system. The polymer breaking system includes an oxidizing breaking agent and an activator capable of providing a bisulfite ion source. A method of treating a subterranean formation may also be performed by forming a treatment fluid comprising an aqueous hydrated polymer solution and a polymer breaking system. The polymer breaking system includes a breaking agent of an oxidizer and an activator capable of providing a bisulfite ion source. The treatment fluid is introduced into the formation.

Abstract: A method and apparatus for the management of injection and production of well fluids in a subterranean well is described to optimize the use of stimulation fluids to enhance their compatibility with subterranean reservoirs and the surface environment and thereby reducing the damage said fluids induce in subterranean reservoirs and upon flow back to the surface reduce their damage to the environment is described. More specifically, this method is directed to the subterranean treatment of injection fluids.

Abstract: A process for reducing the viscosity of fracturing fluids in downhole oilfield operations is provided. The process comprises contacting a sulfamate stabilized, bromine-based breaker with an aqueous polysaccharide fracturing fluid, with the breaker present in an amount to reduce the viscosity of the fracturing fluid. A composition which comprises a sulfamate stabilized, bromine-based breaker for use in decreasing the viscosity of an aqueous polysaccharide fracturing fluid for use in subterranean oil and gas wells is also provided.

Abstract: Compositions and methods pertaining to the ultrafine grinding of soft materials are disclosed. In one embodiment, a method comprises the step of mixing a soft material with an additive to form a mixture. The method further comprises raising the temperature of the mixture to at least the glass transition temperature of the soft material. The method further comprises cooling the temperature of the mixture. The method further comprises grinding the mixture to form ultrafine particles that comprise at least a portion of the soft material.

Abstract: The aqueous polymer composition comprises a water soluble polymer having a molar weight of at least 104 Daltons and comprising functional groups which may form complexes with metal ions. The aqueous polymer compositions of this invention are stabilized against thermal or other degradation processes by addition of a phenothiazine compound to allow their use even under harsh conditions.

Abstract: Adding relatively low molecular weight water-soluble friction loss reduction polymers to an aqueous fluid gelled with a viscoelastic surfactant (VES) increases the critical generalized Reynold's number at which the Fanning friction factor increases and friction pressure starts to increase rapidly. The water-soluble polymeric friction loss reduction additives lower surface pumping pressure in VES-gelled fracturing fluids for a given pump rate, thus lowering hydraulic horsepower (HHP) requirements for pumping fluids downhole, e.g. for hydraulic fracturing or frac packing treatments of subterranean formations.

Abstract: An embodiment of the present invention includes a method comprising introducing a cyclodextrin modifier into a well bore penetrating a subterranean formation. Another embodiment of the present invention includes a method of reducing viscosity of a treatment fluid comprising contacting a treatment fluid comprising a base fluid and a viscosifying agent with at least a cyclodextrin modifier wherein the cyclodextrin modifier interacts with the viscosifying agent to reduce viscosity of the treatment fluid. Another embodiment of the present invention includes a method of increasing viscosity of an aqueous fluid comprising contacting at least a hydrophobically modified polymer and a cyclodextrin modifier in the presence of at least the aqueous fluid, wherein the cyclodextrin modifier interacts with the hydrophobically modified polymer to viscosify the aqueous fluid. Another embodiment of the present invention includes a subterranean treatment fluid comprising a base fluid and a cyclodextrin modifier.

Abstract: This invention relates to compositions used in treating subterranean formations, which include a hydrated polymer, and a dry blended multi-functional component. The hydrated polymer and dry blended multi-functional component are mixed at the ground surface of a wellsite, and subsequently injected into the formation providing controlled delay in crosslinking to achieve targeted fluid viscosity properties. The hydrated polymer may be a guar, hydroxypropyl guar, carboxymethyl guar, carboxymethylhydroxypropyl guar, synthetic polymers, and guar-containing compounds. The dry blended multi-functional component may include a crosslinker and a chelating agent, and the well treatment fluid may further include an activator mixed with the hydratable polymer. The chelating agent may be a polyols, gluconate, sorbitol, mannitol, carbonate, or any mixtures thereof.

Abstract: A lost circulation material and method for treatment employing the material is provided that has particular utility in offshore applications because the material may be used with saltwater or brine, as well as with fresh water, and is biodegradable. The material comprises a biodegradable superabsorbent polysaccharide polymer that is preferably uncrosslinked and non-ionic and that is capable of absorbing multiple times its weight in sea water.