Abstract: The present invention relates to a chemical additive for use with treatment fluids suitable for removing contaminants from oil and gas wells. In one preferred embodiment, the additive includes: a first surface-active agent having an HLB in a range of about 5 to about 9; a second surface-active agent having an HLB in a range of about 11 to about 13; a third surface-active agent having an HLB in a range of about 14 to about 33; a coupling agent; and a coalescing solvent.

Abstract: It has been discovered that fracturing fluid breaker mechanisms are improved by the inclusion of a catalyzed polyol alone that directly degrades the polysaccharide backbone, and optionally additionally by removing the crosslinking ion, if present. That is, viscosity reduction (breaking) occurs by breaking down the chemical bonds within the backbone directly. The gel does not have to be crosslinked for the method of the invention to be successful, although it may be crosslinked. In one non-limiting embodiment, the polyol has at least two hydroxyl groups on adjacent carbon atoms. In another embodiment, the polyols are simple sugars and sugar alcohols, and may include mannitol, sorbitol, glucose, fructose, galactose, mannose, lactose, maltose, allose, etc. and mixtures thereof. The catalyzing metal ion may employ a metal selected from Groups VIB, VIIB, VIII, IB, and IIB of the Periodic Table (previous IUPAC American Group notation).

Abstract: Compositions and methods for the inhibition of salt formation in oil and gas wells are disclosed. In particular, nitrilotriacetamide and its salts are effective at treating existing salt formations, and in inhibiting formation of new deposits.

Abstract: The present invention relates to improved methods for completing well bores along producing zones and, more particularly, to methods for strengthening near well bore subterranean formations. Some embodiments of the present invention provide a method of strengthening the near well bore region of a subterranean formation comprising the steps of isolating a zone of interest along a well bore; either hydrajetting a slot in the zone of interest or acidizing the zone of interest to create wormholes; filling the slot or wormholes with a consolidation material wherein the viscosity of the consolidation material is sufficient to enable the consolidation material to penetrate a distance into the formation; and, allowing the consolidation material to substantially cure.

Abstract: The present invention is directed to an under-neutralized alkylxylene sulfonic acid composition for enhanced oil recovery processes. The present invention is also directed to a method for enhancing the recovery of oil from a subterranean reservoir which method employs the under-neutralized alkylxylene sulfonic acid compositions of the present invention. The under-neutralized alkylxylene sulfonic acid compositions are employed in an aqueous media. The method optionally employs suitable co-surfactants, such as alcohols, alcohol ethers, polyalkylene glycols, poly(oxyalkylene)glycols and/or poly(oxyalkylene)glycol ethers.

Abstract: A method to clean the wellbore and the near wellbore formation adjacent to the wellbore of the gas bearing formation adjacent to the production zone of the wellbore. The method includes the steps of injecting a treatment liquid containing from 84.5 to 100% of liquid carbon dioxide, 0 to 15% of an alcohol, and 0 to 0.5% of a surfactant into the well in a predetermined quantity and maintaining the pressure of the treatment liquid in the near wellbore formation of the gas bearing formation below the fracturing pressure of the formation, releasing the pressure on the wellbore and allowing the liquid CO2 to vaporize and other materials to blow out of the well.

Abstract: A new composition for a spotting fluid and a method of using such spotting fluid for freeing differential stuck pipe in a subterranean well drilling operation is disclosed. The composition comprises an invert water-in-oil emulsion comprising iso-butyl oleate as its external phase and glycerin as the internal phase. In an alterative embodiment, calcium chloride and water may be substituted for glycerin.

Abstract: Acid based micro-emulsions are disclosed comprising water, an acid blend, an anionic surfactant, a nonionic surfactant, a co-solvent, a solvent and an oxidizer. The micro-emulsions have particular utility in cleaning oil sludges and drilling mud residues from well cuttings, well formations and down hole and surface oil well drilling and production equipment.

Abstract: A method of isolating a subterranean zone using a sealant composition comprising a partially polymerized furfuryl compound selected from the group consisting of furfuryl alcohol, furfuryl aldehyde, and combinations thereof, and pumping the sealant composition into a well bore positioned adjacent to the subterranean zone. A conduit is placed in the well bore to allow the sealant composition to be pumped into the well bore. The sealant composition is pumped down through the conduit and up through an annulus disposed between the conduit and walls of the well bore. After the sealant composition has cured in the annulus, it isolates the interior of the conduit from the subterranean zone and attaches the conduit to the walls of the well bore. In an embodiment, the weight ratio of the polymerized furfuryl compound to the non-polymerized furfuryl compound in the sealant composition ranges from about 1:1 to about 10:1.

Abstract: Method is provided for increasing the productivity of gas wells producing from reservoirs where retrograde condensation occurs around the wells. An oil-wetting surfactant is injected in a solvent to oil wet the formation for a selected distance around a well or a hydraulic fracture intersecting the well. A pre-flush liquid, such as carbon dioxide, alcohol or similar products and mixtures thereof, may be used to reduce water saturation before injection of the surfactant. The method may also be applied to increase the productivity of oil wells producing from reservoirs where breakout of solution gas occurs near the well.

Abstract: Aqueous liquid compositions for increasing the permeability of a subterranean formation are disclosed, the compositions being characterized by provision of fluoborate anion (fluoboric acid) and a specified compound or compounds, or mixture thereof, which chelate aluminum ions and aluminum fluoride species. Methods of treating a subterranean formation by injection of the composition(s) into the formation are also described.

Abstract: A composition, formulation, and method for removing water from a near-wellbore portion of a subterranean formation containing a crude oil and penetrated by a wellbore. The formulation contains alkylpolyglycoside, ethoxylated alcohol and linear alkyl alcohols. The composition contains a hydrocarbonaceous liquid, alkylpolyglycoside, ethoxylated alcohol and linear alkyl alcohol.

Abstract: Methods and compositions are disclosed for controlled addition of components that decrease the viscosity of the viscoelastic surfactant fluids or for controlled changes in the electrolyte concentration or composition of the viscoelastic surfactant fluids. One aspect of the invention relates to the use of internal breakers with a delayed activation. Another aspect of the invention relates to the use of precursors that release a breaking system such as alcohol by a process such as melting, slow dissolution, reaction with a compound present in the fluid or added to the fluid during or after the step of injecting, rupture of an encapsulating coating and de-adsorption of a breaking agent absorbed into solid particles. In another aspect of the invention, alcohols are included in a pad to reduce the low-shear viscosity and reduce the resistance to flow of the treatment fluids during a desired phase of the treatment.

Abstract: Methods of fracturing subterranean zones with less pumping are provided. The methods basically comprise the steps of providing an aqueous fracturing fluid comprised of a brine having a density in the range of from about 9 to about 19 pounds per gallon, pumping the aqueous fracturing fluid into the subterranean zone at a rate and pressure sufficient to fracture the subterranean zone and recovering the aqueous fracturing fluid from the subterranean zone.

Abstract: A storable cement system comprises a suspending agent, a cement spacer and water. The composition may further optional contain a surfactant and/or an organic solvent and/or a weighting material. The suspending agent is preferably a carrageenan or scleroglucan. The cement system may be stored for an extended period of time prior to being interposed between a cement slurry and a drilling fluid. As such, the aqueous cement system may be made off-site and used when desired for preventing contact between non-compatible hydrocarbonaceous and aqueous fluids.

Abstract: A composition, formulation, and method for removing water from a near-wellbore portion of a subterranean formation containing a crude oil and penetrated by a wellbore. The formulation contains alkylpolyglycoside, ethoxylated alcohol and linear alkyl alcohols. The composition contains a hydrocarbonaceous liquid, alkylpolyglycoside, ethoxylated alcohol and linear alkyl alcohol.

Abstract: A low molecular weight, high melting point, crystalline, oil soluble additive for use in wellbore fluids is provided that is preferably a ground crystalline material of melting point over 80° C., preferably over 100° C. which is readily soluble in produced hydrocarbons such as crude oil and lighter condensates, and which exhibits a molecular weight of less than 1000, and preferably less than 500, and more preferably less than 300. Its particle size can be adjusted to bridge efficiently across different pore size formations and control its solubility rate.

Abstract: Disclosed is a hydrophilic, water soluble polymer concentrate for addition to aqueous liquids to enhance the properties thereof, particularly to increase the viscosity or decrease the fluid loss of well drilling and servicing fluids, the concentrate comprising a hydrophobic, water insoluble liquid, an organophilic clay suspension agent, the water soluble polymer, and a stabilizing agent comprising one or more acids in an amount from about 0.001% to about 1.5%, one or more anionic surfactants in an amount from about 0.001% to about 1.0%, one or more nonionic surfactants in an amount from 0.001% to about 0.625% and, from about 0% to about 0.75% of one or more water soluble organic liquids, wherein the total concentration of the stabilizing agent is from about 0.1% to about 2.5%, these percentages being based on the weight of the concentrate.

Abstract: A wellbore fluid having a non-aqueous continuous liquid phase that exhibits an electrical conductivity of not less than 10 &mgr;S m−1 at 1 kHz comprises a polar organic liquid (POL) which exhibits a dielectric constant of at least about 5.0 and a Hildebrand Solubility Parameter of at least about 17 (J cm−3)1/2. Oils or other organic liquids (OL) known to be suitable as the continuous liquid phase of wellbore fluids, may be used in admixture with POL component. Certain inorganic salts, organic bases, quaternary ammonium salts or hydroxides (the dissolved component, DC), display sufficient solubility (and current carrying abilities) in POL, OL or in mixtures of liquid (POL) and liquid (OL) to further improve the electrical conductivity of the mixture. The wellbore fluid can be used for providing enhanced information from electrical logging tools, measurement while drilling, logging while drilling, geosteering and the like.

Abstract: A method of stabilizing a clayey geological formation surrounding a hydrocarbon well is described. It comprises the step of treating the formation with a first reactant and a second reactant, characterized in that a reaction of said first and said second reactant is essentially initiated in the presence of clayey material. The reaction can be characterized by substrate intercalation or condensation stabilization with no pH adjustment or stabilization through reaction of glycol with a carbonyl group containing second reactant or a reaction involving an epoxide ring opening under neutral or acidic conditions.

Abstract: A method of treating a well including injecting a thermally stable, substantially water-free well-treating fluid into the well, wherein the well-treating fluid comprises a polymer, a glycol compound, and a salt is disclosed. In another embodiment, a thermally stable, substantially water-free well fluid including a polymer, a diol compound, and a salt is disclosed.

Abstract: The present invention provides cement compositions comprising an improved fluid loss control additive, and methods for cementing in a subterranean formation using such cement compositions. The cement compositions comprise a hydraulic cement, water, and a fluid loss control additive comprising at least two polymers connected by a pH-sensitive crosslink. Optionally, other ingredients may be included in the compositions.

Abstract: A high temperture aqueous based zirconium (IV) crosslinked guar fracturing fluid having a pH from about 9 to about 12 includes a polymer solution and a zirconium (IV) crosslinking agent in an amount from about 0.1 PPTG to about 5 PPTG of the polymer solution. The polymer solution includes an aqueous fluid, natural guar gum in an amount from about 10 PPTG to about 100 PPTG of the aqueous fluid, a stabilizer in an amount from about 1 PPTG to about 50 PPTG of the aqueous fluid, a non-delayed alkaline buffer in an amount from about 1 PPTG to about 40 PPTG of the aqueous fluid, and a gelation delaying agent in an amount from about 0.25 PPTG to about 3.75 PPTG of the aqueous fluid, where those agents are combined to produce a fracturing fluid suitable to the purposes of hydraulically fracturing subterranean formations with static bottom-hole temperatures greater than 250° F.

Abstract: This invention is directed to a composition comprising expandable cross linked polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of about 1,000 to less than about 9,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers and to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

Abstract: A formation treating fluid comprises one or more borate esters, a liquid carrier and, one or more cross linkable polymer wherein the formation treating fluid has an alkaline pH when the formation treating fluid is positioned in a formation. The formation treating fluid is useful in high temperature operations such as hydraulic fracturing.

Abstract: A new composition for a spotting fluid and a method of using such spotting fluid for freeing differential stuck pipe in a subterranean well drilling operation is disclosed. The composition comprises an invert water-in-oil emulsion comprising iso-butyl oleate as its external phase and glycerin as the internal phase. In an alternative embodiment, calcium chloride and water may be substituted for glycerin.

Abstract: A brine for use during drilling operations, preferably a completion brine, comprising an amount of a low molecular weight water-soluble organic compound effective to reduce the crystallization point of the brine. The low molecular weight water soluble organic compound can be a variety of compounds, with preferred compounds being ethylene glycol, tripropylene glycol bottoms, and combinations thereof. A method of lowering the crystallization point of the brine using a low molecular weight water soluble organic compound also is provided.

Abstract: This invention relates to a wellbore treatment fluid and a method of enhancing wellbore treatment fluids to increase efficiency and productivity of wells. More specifically this invention provides methods for enhancing the thermal stability of wellbore treatment fluids such as drill-in, completion, work-over, packer, well treating, testing, spacer, or hole abandonment fluids. The methods include providing a wellbore treatment fluid that includes a polyol selected from glycerol, glycols and polyglycols as well as a polysaccharide viscosifier. The fluid prepared for use in this invention find particularly advantageous use as a completion fluid and as a fluid loss pill. However, the fluid can include a wide variety of additional agents to modify the physical and chemical properties of the wellbore treatment fluid.

Abstract: Compositions and methods for the inhibition of salt formation in oil and gas wells are disclosed. In particular, nitrilotriacetamide and its salts are effective at treating existing salt formations, and in inhibiting formation of new deposits.

Abstract: A subterranean fracturing fluid, which is relatively harmless to both the environment and subterranean formations includes an amphoteric surfactant, specifically a betaine surfactant and an organic electrolyte or an alcohol in an aqueous medium. Depending upon the proportions of the ingredients, the fluid can be foamed.

Abstract: It has been discovered that borate crosslinked fracturing fluid breaker mechanisms are improved by the inclusion of a polyol together with an enzyme. In fact, synergistic results may be achieved when both are used together as contrasted to the cases where each are used separately. Removing the borate ion from the crosslinked polymer reduces the pH of the fluid and in turn increases the activity of the enzyme. That is, once the pH is lowered, viscosity reduction (breaking) occurs by uncrosslinking of the polymer within the fracturing fluid, and by initiating or increasing activity of an enzyme breaker, if present. In one embodiment, the polyol has at least two cis-hydroxyl groups. In another embodiment, the polyols are monosaccharides such as glycerols and sugar alcohols, and may include mannitol, sorbitol, glucose, fructose, galactose, mannose, allose, etc. and mixtures thereof. Oligosaccharides and derivatives of monosaccharides and oligosaccharides are also useful.

Abstract: This invention is directed to a composition comprising expandable cross linked polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of about 1,000 to less than about 9,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers and to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

Abstract: Acid based micro-emulsions are disclosed comprising water, an acid blend, an anionic surfactant, a nonionic surfactant, a co-solvent, a solvent and an oxidizer. The micro-emulsions have particular utility in cleaning oil sludges and drilling mud residues from well cuttings, well formations and down hole and surface oil well drilling and production equipment.

Abstract: A microemulsion comprising (i) an oil phase, (ii) an aqueous phase comprising an aqueous solution of a water soluble oil field or gas field production chemical or an aqueous dispersion of a water dispersible oil field or gas field production chemical and (iii) at least one surfactant, wherein the aqueous phase is distributed in the oil phase in the form of droplets having a diameter in the range 1 to 1000 mn or in the form of microdominans having at least one dimension of length, breath or thickness in the range 1 to 1000 nm.

Abstract: A method of preventing corrosion in pipelines comprising draining pipeline of all residual compounds, blowing through with nitrogen and rinsing with a corrosion inhibiting rinsing agent.

Abstract: It has been discovered that borate crosslinked fracturing fluid breaker mechanisms are improved by the inclusion of a polyol together with an enzyme. In fact, synergistic results may be achieved when both are used together as contrasted to the cases where each are used separately. Removing the borate ion from the crosslinked polymer reduces the pH of the fluid and in turn increases the activity of the enzyme. That is, once the pH is lowered, viscosity reduction (breaking) occurs by uncrosslinking of the polymer within the fracturing fluid, and by initiating or increasing activity of an enzyme breaker, if present. In one embodiment, the polyol has at least two cis-hydroxyl groups. In another embodiment, the polyols are monosaccharides such as glycerols and sugar alcohols, and may include mannitol, sorbitol, glucose, fructose, galactose, mannose, allose, etc. and mixtures thereof. Oligosaccharides and derivatives of monosaccharides and oligosaccharides are also useful.

Abstract: The reaction of propargyl alcohol and iodine gives 2,3di-iodo-2-propen-1-ol, and it has been discovered that this compound is effective as an intermediate in a corrosion inhibitor for metals in acid media, particularly halogen acids. The compound provides iodine to the media in a stable form that does not appear to degrade over time.

Abstract: This invention relates to a well treatment fluid and a method to treat an/or fracture a subterranean formation comprising: injecting a well treatment fluid into the formation at sufficient pressure to fracture the formation wherein the fluid comprises: (a) one or more amphoteric surfactants; (b) water; (c) one or more nonaqueous solvents; (d) optionally, an acid forming compound; and (e) provided that if the acid forming compound is present a hydrophilic alcohol may also be optionally present; wherein the all or part of the fluid forms vesicles.

Abstract: This invention relates to a wellbore treatment fluid and a method of enhancing wellbore treatment fluids to increase efficiency and productivity of wells. More specifically this invention provides methods for enhancing the thermal stability of wellbore treatment fluids such as drill-in, completion, work-over, packer, well treating, testing, spacer, or hole abandonment fluids. The methods include providing a wellbore treatment fluid that includes a polyol selected from glycerol, glycols and polyglycols as well as a polysaccharide viscosifier. The fluid prepared for use in this invention find particularly advantageous use as a completion fluid and as a fluid loss pill. However, the fluid can include a wide variety of additional agents to modify the physical and chemical properties of the wellbore treatment fluid.

Abstract: A new composition for a spotting fluid and a method of using such spotting fluid for freeing differential stuck pipe in a subterranean well drilling operation is disclosed. The composition comprises an invert water-in-oil emulsion comprising iso-butyl oleate as its external phase and glycerin as the internal phase. In an alternative embodiment, calcium chloride and water may be substituted for glycerin.

Abstract: This invention is directed to a composition comprising expandable cross linked polymeric microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 10 microns and a cross linking agent content of from about 9,000 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers and to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

Abstract: A new stable liquid suspension containing non-soluble particles dispersed in a non-aqueous liquid medium having a concentration of a suspension aid and a method of making and use thereof.

Abstract: A microemulsion comprising, (i) an oil phase, (ii) an aqueous phase comprising an aqueous solution of a water soluble oil field or gas field production chemical or an aqueous dispersion of a water dispersible oil field or gas field production chemical and (iii) at least one surfactant, wherein the aqueous phase is distributed in the oil phase in the form of droplets having a diameter in the range 1 to 1000 mn or in the form of microdomains having at least one dimension of length, breath or thickness in the range 1 to 1000 nm.

Abstract: This invention relates to a well treatment fluid and a method to treat an/or fracture a subterranean formation comprising: injecting a well treatment fluid into the formation at sufficient pressure to fracture the formation wherein the fluid comprises: (a) one or more amphoteric surfactants; (b) water; and (c) one or more nonaqueous solvents; (d) optionally, an acid forming compound, and (e) provided that if the acid forming compound is present a hydrophilic alcohol may also be optionally present.

Abstract: The invention provides solids-free, viscous fluids (pills) for use in various well workover and completion operations including as displacement spacer pills, standard fluid loss control pills, post gravel pack in-screen pills, perforation sealing, and the like. The pills comprise a viscous solution of a polyethylene glycol having a molecular weight of 1,000 to 8,000,000 in an aqueous liquid comprising a solution of one or more soluble bromide salts having a density sufficient to provide the desired hydrostatic pressure at the location of use of the fluid in a well. The minimum concentration of the polyethylene glycol in the pill varies with the average molecular weight as follows: MW=1,000 to 10,000=100 ppb; MW=10,001 to 100,000=75 ppb; MW=100,001 to 250,000=50 ppb; MW=250,001 to 500,000=10 ppb; MW=500,001 to 8,000,000=5 ppb.

Abstract: Methods and acidizing compositions for reducing the corrosion of the metal surfaces of tubular goods and the like and reducing the precipitation of metal sulfide from the acidizing compositions are provided. The methods basically comprise the steps of combining an aldol-amine adduct with an aqueous acid solution to preferentially react with sulfide ions subsequently dissolved by the aqueous acid solution and thereby prevent subsequently dissolved metal ions from reacting therewith and precipitating, and then introducing the aqueous acid solution containing the aldol-amine adduct into a well or other location to be acidized.

Abstract: A process for cleaning boreholes, drilling equipment and drill cuttings is presented involving the application of a cleaning composition to surfaces and the subsequent removal of the cleaning composition and soils. The cleaning composition contains a cleaning additive having alkoxylation products obtained by the reaction of ethylene oxide, propylene oxide, butylene oxide or mixtures thereof with an OH-containing C10-22 carboxylic acid or derivative thereof, where structural units corresponding to formula (I): comprise one or both of the 9/10 or 13/14 positions, wherein R1 is a hydrogen atom, an OH group or a OR2 group, R2 is an alkyl group containing 1 to 18 carbon atoms, an alkenyl group containing 2 to 18 carbon atoms or a group corresponding to formula (II): where R3 is a hydrogen atom, an alkyl group containing 1 to 21 carbon atoms or an alkylene group containing 2 to 21 carbon atoms. The cleaning composition is biodegradable.

Abstract: A mutual solvent for use in oil and gas well operations comprising 2,2,4-trimethyl-1,3-pentanediol monoisobutyrate and/or 2,2,4-trimethyl-1,3-pentanediol diisobutyrate, a coupling solvent, and an acid stable surfactant. The coupling solvent is selected from ethylene glycol monobutyl ether; diethylene glycol monobutyl ether; propylene glycol monomethyl ether acetate; propylene glycol monomethyl ether; C1-C5 alkyl alcohol; and mixtures thereof. The invention also relates to an emulsion for use in oil and gas well operations comprising an aqueous acid or acid-salt brine solution and the mutual solvent as described above. An emulsion according to the invention is stable, non-toxic, and effectively removes asphaltenic and paraffinic hydrocarbons from drilling equipment and oil and gas wells.

Abstract: A method and composition for removing deposits of heavy hydrocarbonaceous materials and finely divided inorganic particulate matter from wellbore and flowline surfaces using a composition containing an alkyl polyglycoside, an ethoxylated alcohol, a caustic and an alkyl alcohol.

Abstract: A drilling, drill-in, or completion fluid comprising water as a continuous phase, said continuous phase comprising a gas hydrate inhibiting amount of a blend comprising an ethylene glycol derivative and a propylene glycol derivative. The propylene glycol derivative is present in an amount effective to inhibit hydration of shale by the water base. The density of the fluid may be reduced by substituting the blend for salt, and by increasing the amount of propylene glycol derivative in the blend. The blend preferably should comprise at least about 10 vol % of the fluid, and a preferred ratio in the blend is about 35 vol % tripropylene glycol bottoms to about 65 vol % ethylene glycol.