Abstract: Provided is a wellbore casing liner printing system that includes a casing liner print head adapted to be disposed in an annular region located between a casing pipe disposed in a wellbore of a hydrocarbon well and a wall of the wellbore and adapted to rotate within the annular region and deposit material into the annular region to form a casing liner in the annular region. The casing liner print head including a first set of printing nozzles arranged in series in a radial direction, and a second set of printing nozzles arranged in series in the radial direction and offset from the first set of printing nozzles. The first set of printing nozzles adapted to eject a first casing liner material into the annular region and the second set of printing nozzles adapted to eject a second casing liner material into the annular region to form the casing liner of the first casing liner material and the second casing liner material.

Abstract: Provided are systems and method for casing a wellbore of a hydrocarbon well. The casing including disposing a casing print head in a wellbore of a hydrocarbon well, and conducting a downhole casing operation including operating the casing print head to eject casing material to form a casing tubular in the wellbore, and operating the casing print head to eject casing liner material into an annular region located between the casing tubular and a wall of the wellbore to form a casing liner in the annular region, the casing tubular and the casing liner forming a casing of the wellbore.

Abstract: Provided are systems and methods for forming a casing liner in a wellbore of a hydrocarbon well. The forming including disposing a casing liner print head in an annular region located between a casing pipe disposed in a wellbore of a hydrocarbon well and a wall of the wellbore, conducting a downhole lining operation including operating the casing liner print head to eject casing liner integrated structure material into the annular region to form, in the annular region, a casing liner integrated structure including contiguous voids formed in the casing liner integrated structure material, and depositing a cementitious material into the contiguous voids formed in the casing liner material to form, in the annular region, a casing liner including the casing liner integrated structure material and the cementitious material.

Abstract: The present disclosure relates to the creation of emulsifiers for use in an oil-based drilling mud. The disclosed emulsifiers may be created by the reaction of synthetic linear saturated fatty acids and polyamines under the conditions specified. The synthesized product may be used as a replacement for the wetting agent in conventional muds. Further improvements in conventional drilling muds are also disclosed where the synthesized product is used to replace incumbent wetting agents and the primary emulsifiers are replaced by synthetic fatty acids.

Abstract: Method for removing hydrogen sulfide from fluids such as oil and gas well drilling, treatment, and production fluids and effluents from hydrocarbon operations and mineral mining operations. The sulfide scavenger used in the method is a gluconate salt other than ferrous gluconate. The gluconate salt is added to the fluid along with an iron source if iron is not already in the fluid. The gluconate reacts with the iron and forms iron gluconate in the fluid, which in turn reacts with the hydrogen sulfate to form iron sulfide which may be readily removed from the fluid.

Abstract: Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids.

Abstract: Method for removing hydrogen sulfide from fluids such as oil and gas well drilling, treatment, and production fluids and effluents from hydrocarbon operations and mineral mining operations. The sulfide scavenger used in the method is a gluconate salt other than ferrous gluconate. The gluconate salt is added to the fluid along with an iron source if iron is not already in the fluid. The gluconate reacts with the iron and forms iron gluconate in the fluid, which in turn reacts with the hydrogen sulfate to form iron sulfide which may be readily removed from the fluid.

Abstract: Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids.

Abstract: A sealant composition comprising an inverse emulsion polymer and methods of servicing a wellbore using the same are disclosed. In one embodiment, a method of servicing a wellbore that penetrates a subterranean formation is disclosed. The method comprises placing a sealant composition comprising an inverse emulsion polymer into the wellbore to reduce a loss of fluid to the subterranean formation during placement of the fluid in the wellbore.

Abstract: Wellbore treatment kits are provide that include a polymeric solution for placement in a wellbore that penetrates a subterranean formation and an activator for causing a polymer to precipitate out of the polymeric solution when it contacts the polymeric solution, wherein the resulting precipitate is capable of at least partially blocking a flow of a wellbore servicing fluid into the subterranean formation. The wellbore servicing fluid may be, for example, a drilling fluid, a cement composition, a workover fluid, or combinations thereof. The polymeric solution may comprise, for example, a poly vinyl pyrrolidone aqueous solution, and the activator may comprise, for example, a formate brine. When desirable, the precipitate may be easily and quickly removed from the subterranean formation by dissolving it in fresh water.

Abstract: Methods are provided for reducing the loss of a wellbore servicing fluid to a subterranean formation. A polymeric solution and an activator may be contacted in the formation, thereby forming a precipitate to at least partially block fluid from flowing further into the formation. The fluid may be, for example, a drilling fluid, a cement composition, a workover fluid, or combinations thereof. The polymeric solution may comprise a polyvinylpyrrolidone aqueous solution, and the activator may comprise a formate brine. In one embodiment, the polymeric solution and the activator are contacted before completing a drilling operation in the wellbore. In another embodiment, they are contacted before completing a primary cementing operation in the wellbore. In yet another embodiment, they are contacted before completing a secondary cementing operation in the wellbore. When desirable, the precipitate may be easily and quickly removed from the subterranean formation by dissolving it in fresh water.

Abstract: A sealant composition comprising an inverse emulsion polymer and methods of servicing a wellbore using the same are disclosed. In one embodiment, a method of servicing a wellbore that penetrates a subterranean formation is disclosed. The method comprises placing a sealant composition comprising an inverse emulsion polymer into the wellbore to reduce a loss of fluid to the subterranean formation during placement of the fluid in the wellbore.

Abstract: A method for using an invert emulsion fluid in a well bore, comprising placing an invert emulsion fluid in a well bore, wherein the invert emulsion fluid comprises an oleaginous fluid, a non-oleaginous fluid and an emulsifier comprising one or more amines generally represented by the formula: wherein R is a radical selected from the group consisting of abietyl, hydroabietyl, dihydroabietyl, tetrahydroabietyl, and dehydroabietyl, each R? may be the same or different and is an alkyl having from about 1 to about 3 carbons, each A may be the same or different and is NH or O, and the sum of x and y ranges from about 1 to about 20, and contacting the invert emulsion fluid with an acid solution to reversibly convert the invert emulsion to an oil-in-water emulsion.

Abstract: New polymers, and their applications in water-based wellbore service fluids, such as, for example, drilling fluids, yield desirable filtration control and rheological properties to such fluids even after exposure to HTHP aging. Typical temperatures encountered during such aging are around 350–400° F. and the duration of the exposure is some significant time such as 16 hours or longer. Preferably, the polymers are random terpolymers of N-vinylcaprolactam, vinyl sulfonate monomer 2-acrylamido-2-methyl-1-propanesulfonic acid, and monomer acrylamide, most preferably in a molar ratio of 15:20:65 respectively. The polymers reduce HTHP filtration volumes in fresh water, sea water, potassium chloride, and lime mud systems. The polymers may also be used to inhibit or reduce shale erosion.

Abstract: An invert emulsion fluid, method for making same, and method for using same as a servicing fluid in a well bore. The invert emulsion fluid contains an oleaginous fluid, a non-oleaginous fluid, and an emulsifier comprising one or more amines generally represented by the formula: wherein R is a cycloaliphatic hydrocarbon, each R? may be the same or different and is H or an alkyl having from about 1 to about 3 carbon atoms, each A may be the same or different and is NH or O, and the sum of x and y ranges from about 1 to about 20. In a preferred embodiment, R is a radical selected from the group consisting of abietyl, dihydroabietyl, tetrahydroabietyl, and dehydroabietyl, R? is H, and A is O.

Abstract: A method and composition is provided for a suspending agent for supporting components in drilling fluids, particularly oil-based drilling fluids, the suspending agent comprising the condensation product of a dimer or trimer fatty acid and diethanolamine.

Abstract: New polymers, and their applications in water-based wellbore service fluids, such as, for example, drilling fluids, yield desirable filtration control and rheological properties to such fluids even after exposure to HTHP aging. Typical temperatures encountered during such aging are around 350-400° F. and the duration of the exposure is some significant time such as 16 hours or longer. Preferably, the polymers are random terpolymers of N-vinylcaprolactam, vinyl sulfonate monomer 2-acrylamido-2-methyl-1-propanesulfonic acid, and monomer acrylamide, most preferably in a molar ratio of 15:20:65 respectively. The polymers reduce HTHP filtration volumes in fresh water, sea water, potassium chloride, and lime mud systems. The polymers may also be used to inhibit or reduce shale erosion.

Abstract: An invert emulsion fluid, method for making same, and method for using same as a servicing fluid in a well bore.

Abstract: A method and composition is provided for a suspending agent for supporting components in drilling fluids, particularly oil-based drilling fluids, the suspending agent comprising the condensation product of a dimer or trimer fatty acid and diethanolamine.

Abstract: This invention relates to drilling fluid additives that suppress clay swelling within a subterranean well and to methods for controlling clay swelling during the drilling of a subterranean well. In one embodiment trihydroxy alkyl amine is reacted with an alkyl halide or a water soluble quaternary amine to form a quaternized trihydroxy alkyl amine. The reaction products can also include condensed reaction products of quaternized trihydroxy alkyl amines. In another embodiment a choline derivative is used. The quaternized reaction products and choline derivatives are characterized by low toxicity and compatibility with anionic drilling fluid components. The products are added to water base drilling fluids which are circulated throughout a well. The drilling fluid additives and the method of controlling clay swelling provide for improved control of the rheological properties of drilling fluids along with increased environmental and drilling fluid compatibility.