Abstract: A well servicing fluid for reducing polymer degradation is disclosed. The well servicing fluid is formulated with components comprising: at least one free radical scavenger, with the proviso that the free radical scavenger is not erythorbate, lignin or lignin derivatives; at least one polymer and an aqueous based solvent. Methods for servicing a well employing well servicing fluids of the present disclosure are also disclosed.

Abstract: A method for forming a well and pipeline treating fluid is provided. The method comprises combining a cross-linkable gelling polymer, a scavenging compound capable of reducing a concentration of divalent and polyvalent metal ions and salts thereof available for reaction, a hydration solvent and optionally an acid. The resulting mixture has a pH ranging from about 3 to about 7 and a first viscosity. The mixture is maintained at conditions suitable for hydration of the cross-linkable gelling polymer until the mixture has a second viscosity that is greater than the first viscosity. The mixture is combined with an aqueous based fluid and at least one cross-linking agent. The pH of the mixture is raised to a sufficient level to allow a desired degree of cross-linking to occur. Other methods, a well and pipeline treating gel and a well and pipeline treating fluid are also provided.

Abstract: An effective amount of a hydrazine complexing agent and/or a non-hydrazine complexing agent may be added to an oil-based fluid having at least one metal. The complexing agent may form an insoluble metal complex with the metal(s). The metal(s) may be or include, but are not limited to zinc metal, nickel metal, iron metal, cations thereof, and combinations thereof. The insoluble metal complex may be or include, but is not limited to a zinc complex, a nickel complex, an iron complex, and combinations thereof. The insoluble metal complex may be removed from the oil-based fluid where the metal may be separated from the insoluble metal complex.

Abstract: Zinc, nickel and iron can be recovered from spent brines and produced water using a method that includes admixing an aqueous fluid with hydrazine to form a hydrazine complex and then filtering or otherwise removing the hydrazine complex from the aqueous fluid. Once treated, the aqueous fluid can then be recycled or at be the subject to an easier disposal. The isolated metal hydrazine complex may be recycled or discarded.

Abstract: A well servicing fluid for reducing polymer degradation is disclosed. The well servicing fluid is formulated with components comprising: at least one free radical scavenger, with the proviso that the free radical scavenger is not erythorbate, lignin or lignin derivatives; at least one polymer and an aqueous based solvent. Methods for servicing a well employing well servicing fluids of the present disclosure are also 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: A method for forming a well and pipeline treating fluid is provided. The method comprises combining a cross-linkable gelling polymer, a scavenging compound capable of reducing a concentration of divalent and polyvalent metal ions and salts thereof available for reaction, a hydration solvent and optionally an acid. The resulting mixture has a pH ranging from about 3 to about 7 and a first viscosity. The mixture is maintained at conditions suitable for hydration of the cross-linkable gelling polymer until the mixture has a second viscosity that is greater than the first viscosity. The mixture is combined with an aqueous based fluid and at least one cross-linking agent. The pH of the mixture is raised to a sufficient level to allow a desired degree of cross-linking to occur. Other methods, a well and pipeline treating gel and a well and pipeline treating fluid are also provided.

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: 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: A method of reclaiming a well completion brine solution containing metal impurities by introducing to the brine solution an organic chelant of the formula: and may be either a neutral compound, a corresponding salt, or a corresponding quaternary salt, wherein: D is F-A (Y3)u(Y4)v; R is independently selected from Cp or CpC(O); Cp is a C1-C36, preferably a C8-C36, hydrocarbyl group, optionally substituted with one or more substituents selected the group consisting of halogen, hydroxyl, sulfate, CH2CO2Z or —(CH2)nPO(OZ)2 groups; each A is independently selected from —N and —P; Y1 is independently selected from J, —[(F)-A(J)]w Y6 and R; J, R1, Y2, Y3, Y4, Y5 and Y6 are independently selected from the group consisting of —H, R, —(F)nCO2Z and —(CH2)nPO(OZ)2; each F is independently selected from a C1-C12 hydrocarbyl group, optionally substituted with one or more substituents selected from the group consisting of halogen, hydroxyl, sulfate, CH2CO2Z or —(CH2)nPO(OZ)2 groups; Z is —H, a balanced organic counte

Abstract: A method of reclaiming a well completion brine solution by using an organic chelant that is capable of discriminating between (i) iron and non-zinc heavy metals; and (ii) calcium and zinc. The chelant contains a functional group selected from the group —CO2H or —PO(R21)R20 or a salt or ester thereof, —C(O)—, —OE, —SE, —N?C(R2)R3, EO—N?C(R2)R3, —N(R2)R3, and —N(C(O)R1)R2 group optionally substituted with a —COOH or —PO(R21)R20 or a salt or ester thereof, —SE or —OE group, wherein R2 and R3 are independently selected from E or forms, with nitrogen, phosphorous, oxygen or sulfur, a heterocyclic ring; E is R1 or —H; R1 is a C1-C30 alkyl or aralkyl group or a derivative thereof and R20 and R21 are independently selected from —OH, —OR1 and R1.

Abstract: Fluid producing or injecting wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted particulates, including pipe dope, asphaltenes and paraffins. In addition, such emulsions are effective in the displacement of oil base drilling muds and/or residues from such muds from wells. The emulsion may also be used to break the interfacial and/or rheological properties of oil base mud and synthetic oil base mud filter cakes, and act as a demulsifier to break the water-in-oil emulsion present in such oil base and synthetic oil base muds. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: An aqueous-based well treatment fluid containing an additive having a median particle size less than 1 micron is suitable for use in a wide variety of well treatment applications including use as a drill-in fluid, thermal insulating fluid, spacer or fluid loss control additive. The fluid may consist of a high density brine. The additive is capable of viscosifying the water or brine. Viscosification of the water or brine may occur in the substantial absence of a polymeric viscosifying agent.

Abstract: Fluid producing or injecting wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted particulates, including pipe dope, asphaltenes and paraffins. In addition, such emulsions are effective in the displacement of oil base drilling muds and/or residues from such muds from wells. The emulsion may also be used to break the interfacial and/or rheological properties of oil base mud and synthetic oil base mud filter cakes, and act as a demulsifier to break the water-in-oil emulsion present in such oil base and synthetic oil base muds. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: A filter cake deposited by a drilling fluid, drill-in fluid or fluid loss control pill may be removed from a wellbore by introducing into the wellbore a dispersing agent of an organic amino phosphonic acid, ester or salt. The dispersing agent forms a dispersion containing at least a portion of the drilled solids. The dispersing agent may be introduced into the wellbore as a component of a filter cake removal treatment fluid or either prior to or after introduction of the filter cake removal treatment fluid.

Abstract: A thermal insulating packer fluid contains water and/or brine, a crosslinkable viscosifying polymer, a crosslinking agent and an optional set retarder. 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 such as to reduce the convection flow velocity within the annulus.

Abstract: A method of reclaiming a well completion brine solution by using an organic chelant that is capable of discriminating between (i) iron and/or non-zinc heavy metals; and (ii) calcium and zinc.

Abstract: A method of reclaiming a well completion brine solution by using an organic chelant that is capable of discriminating between (i) iron and non-zinc heavy metals; and (ii) calcium and zinc. The chelant contains a functional group selected from the group —CO2H or —PO(OH)R20 or a salt or ester thereof, —C(O)—, —OE, —SE, —N?C(R2)R3, EO—N?C(R2)R3, —N(R2)R3, and —N(C(O)R1)R2 group optionally substituted with a —COOH or —PO(OH)R20 or a salt or ester thereof, —SE or —OE group, wherein R2 and R3 are independently selected from E or forms, with nitrogen, phosphorous, oxygen or sulfur, a heterocyclic ring; E is R1 or —H; R1 is a C1–C30 alkyl or aralkyl group or a derivative thereof and R20 is —OH or R1.

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: 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.