Abstract: A method of injection of a higher density fluid into the top of the annulus of a well while lower density fluid is withdrawn from the top of the annulus of the well, wherein the higher density fluid has a composition such that it will drop through the lower density fluid without dispersing therein, thus flowing into the deeper reaches of the annulus and not short circuiting through the top of the annulus to the point from which the lower density fluid is intended to be withdrawn.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: A method of injection of a higher density fluid into the top of the annulus of a well while lower density fluid is withdrawn from the top of the annulus of the well, wherein the higher density fluid has a composition such that it will drop through the lower density fluid without dispersing therein, thus flowing into the deeper reaches of the annulus and not short circuiting through the top of the annulus to the point from which the lower density fluid is intended to be withdrawn.

Abstract: A method of controlling and delaying the inversion of a drilling fluid and the wettability of a filtercake by using a delayed phase changing agent.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.

Abstract: High density, thermally stable, brine-based well fluids and methods of using the same are disclosed. In one embodiment a well fluid including water and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is disclosed. In another embodiment, a well fluid including water, a viscosifying agent, and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is disclosed. A method of treating a well using a well fluid, wherein the well fluid includes water and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is also disclosed.

Abstract: Compositions for increasing the thermal and pressure stability of well fluids viscosified using viscoelastic surfactants, the compositions including an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and at least one pendent viscoelastic surfactant functional group. Preferred compositions for increasing the stability of well fluids viscosified using monomeric viscoelastic surfactants include an effective amount of an oligomeric or polymeric compound that has a thermally stable backbone structure and a multiplicity of pendent viscoelastic surfactant functional groups attached to said backbone structure through relatively long hydrocarbon chains, 1 to 18 carbons in length.

Abstract: A method of treating a well including injecting a well-treating fluid into the well, where the well-treating fluid comprises a glycol compound and an organic liquid, the glycol compound and organic liquid being present in amounts selected to achieve a desired density. In another embodiment, a well fluid including a glycol compound an organic liquid, and a salt, wherein the glycol compound, organic liquid, and salt are present in amounts selected to achieve a predetermined density is disclosed.

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: The present invention relates to methods and compositions for increasing the effective temperature range for viscosified fluids, including particularly fluids that have been viscosified by the addition of a natural or a natural derivative polymer. In one embodiment, the present invention relates to a method for increasing the effective temperature range for a polymer-viscosified fluid used as a well fluid, which includes adding a miscible tertiary, secondary, and/or primary amine compound into a polymer solution. In another embodiment, the present invention relates to a thermally stable well fluid, which includes a polymer, a solvent, and a tertiary, secondary, and/or primaryamine miscible in the solvent.

Abstract: High density, thermally stable, brine-based well fluids and methods of using the same are disclosed. In one embodiment a well fluid including water and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is disclosed. In another embodiment, a well fluid including water, a viscosifying agent, and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is disclosed. A method of treating a well using a well fluid, wherein the well fluid includes water and a salt, the salt including at least one formate salt, wherein the weight-to-volume ratio of the well fluid is within the range of at least 120% to about 400% is also disclosed.

Abstract: The present invention relates to methods and compositions for increasing the effective temperature range for viscosified fluids, including particularly fluids that have been viscosified by the addition of a synthetic polymer. In one embodiment, the present invention relates to a method for increasing the effective temperature range for a synthetic polymer-viscosified fluid used as a well fluid, which includes adding a miscible tertiary, secondary, and/or primary amine compound into a polymer solution. In another embodiment, the present invention relates to a thermally stable well fluid, which includes a synthetic polymer, a solvent, and a tertiary, secondary, and/or primary amine miscible in the solvent.

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: This invention relates to novel compositions and methods whereby a carboxylate based brine solution is used in drilling and/or well bore treating operations to inhibit corrosion of fluid handling equipment. In one embodiment of the invention the carboxylate based brine solution consists of a carboxylate salt dissolved in water. This brine solution is used to prepare halide-free drilling fluids. Use of halide-free drilling fluids inhibits corrosion stainless steel surfaces of fluid handling equipment. In an alternative embodiment of the present invention a mixed salt brine containing a carboxylate salt and a halide salt is provided for use in a drilling and/or well bore treating operations.

Abstract: Advantageous aqueous mixed salt systems viscosified with water-soluble or water-dispersable polymers which are superior to corresponding single salt systems of similar densities are provided. The mixed salt systems comprise water; a water-soluble or water-dispersable polymer capable of viscosifying an aqueous medium; one or more cations including a member selected from the group consisting of lithium, sodium, potassium, cesium, magnesium, calcium, zinc, or mixtures thereof; and one or more anions including a member selected from the group consisting of chloride, bromide, iodide, formate, nitrate, acetate, cyanate, thiocyanate, a zinc complex anion or mixtures thereof; there being present either at least two cations or at least two anions. Inventive viscosified mixed salt systems display--under such stressing factors as aging, heat, mechanical agitation, and shear--greater stability compared to the single salt systems of similar densities.

Abstract: The present invention provides compositions useful for viscosifying aqueous fluids, methods for making them and methods for using them. In one aspect of the invention, inventive compositions comprise a prehydrating alcohol having at least two hydroxyl groups and having a molecular weight of from about 60 to about 600; an inorganic salt; and a polymer. In a preferred aspect of the invention, the viscosifier composition additionally comprises a solvent having a molecular weight of from about 75 to about 1000. According to another aspect of the invention, inventive compositions comprise a prehydrating alcohol; an inorganic salt; and a polymer; and the composition is essentially free from water. Inventive compositions find advantageous use in viscosifying fluids utilized in subterranean drilling activities such as, for example, drilling, drill-in, completion, hydraulic fracturing, work-over, packer, well treating, testing, spacer, or hole abandonment fluids.

Abstract: A continuous method of in situ steam generation for steamflooding which comprises injecting a mixture of hydrocarbons to serve as fuel for in situ combustion and water to be converted into steam by the hot formation into an upper zone of the formation, while simultaneously injecting into the lower zone an oxidant causing at least a portion of the oxidant to contact and combust with the injected hydrocarbons.

Abstract: A batch method of in situ steam generation for steamflooding which comprises injecting hydrocarbons into an upper zone of the formation to serve as fuel for in situ combustion, injecting oxidant into the lower zone causing at least a portion of the oxidant to contact and combust with the injected hydrocarbons, injecting water into the upper zone to be converted into steam by the hot formation, followed by ceasing oxidant injection, injecting a non-oxidant material into the lower zone so that the combustion zone does not approach the wellbore, and generating a steam front to drive formation hydrocarbons towards at least one production well.

Abstract: A method of recovering hydrocarbons from an underground reservoir with a cyclic injection/production process, wherein after one or more injection and production cycles, a second recovery fluid is injected into the formation comprising a cosolvent, a solute, preferably polydimethylsiloxane, and the primary recovery fluid such as carbon dioxide, said second fluid composition designed for solute to drop out of solution in the formation during the later soaking and production phases.

Abstract: A low volume photographic material processing apparatus that utilizes a narrow horizontal processing channel. A replenishment pump calibration system is integrated into the processor so that no manual measurements or special tools are required to set replenishment solution rates.