Abstract: Provided are compositions containing a mixture of microcapsules and a bulk polymer, where the microcapsules have an oil field chemical contained within the microcapsules. The microcapsules can be present in a variety of configurations. The microcapsules contain a core or a micro-matrix containing the oil field chemicals. The core or micro-matrix can be surrounded by one or more polymeric shells, where each shell contains at least one polymer that affects the release of the oil field chemical from the composition. The compositions provide for the sustained release of an oil field chemical into fluid in an oil field reservoir over long periods of time. Also provided are methods of making the compositions and articles containing the compositions, along with methods are of tracing the movement of fluid in a hydrocarbon reservoir using the compositions, and methods of providing for the sustained release of oil field chemicals.

Abstract: The present invention relates to drilling fluid compositions and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation including obtaining or providing a drilling fluid composition including a viscosifier including at least one of a poly(vinyl alcohol) copolymer, a crosslinked poly(vinyl alcohol), and a crosslinked poly(vinyl alcohol) copolymer. The method also includes placing the composition in a subterranean formation.

Abstract: Systems and methods for the use of degradable polymers that are dissolved and/or plasticized in an organic solvent in subterranean treatments. In some embodiments, the methods comprise: providing a treatment fluid that comprises at least one organic solvent and one or more degradable polymers, wherein the treatment fluid does not comprise a significant amount of solid material comprising the one or more degradable polymers; introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation; and contacting the treatment fluid with one or more aqueous fluids to form a solid precipitate comprising the one or more degradable polymers in the portion of the subterranean formation.

Abstract: A method for adjusting, to a pre-determined value, the level of a mineral deposition or corrosion inhibitor injected into a gas or oil well. Using of the time-resolved fluorescence method for detecting and quantifying a mineral deposition or corrosion inhibitor in a fluid from an oil or gas production well.

Abstract: A method and a system for recovering oil from currently inaccessible oil containing geological units by activating the deep biosphere microbial seed bank. Nutrient and thermal enhancement of microorganisms in oil containing geological units allows for stimulation of inactive and/or dormant microorganisms such that they proliferate and produce gas. The oil viscosity that is decreased by heat, along with the gas pressure produced by activated microbes which allows previously inaccessible oil to flow toward production wells.

Abstract: Methods and systems that utilize reactive metals that hydrate in the presence of a wellbore fluid. The reactive metals can be utilized in cement compositions, on the outer surface of the oilfield tubular in the form of a layer of the reactive metal(s), or on the outer surface of the oilfield tubular in the form of a layer of a composition that includes the reactive metal(s).

Abstract: A method of treating a subterranean formation includes introducing a well cementing composition into a wellbore, said cementing composition comprising: a pumpable slurry of cement and at least one of hydrophobic material, a superhydrophobic material, and combinations; and allowing at least a portion of the cementing composition to cure. A composition includes a pumpable slurry of wellbore cement and at least one of hydrophobic material, a superhydrophobic material, and combinations thereof.

Abstract: A method includes collecting tracer concentration measurements from a flow stream in a borehole as a function of time. The method also includes recovering an uplink telemetry signal from the collected tracer concentration measurements, wherein the uplink telemetry signal conveys a downhole tool measurement or communication. The method also includes performing an operation in response to the recovered uplink telemetry signal.

Abstract: Compositions and methods for the controlled delivery of acid to a desired location. In some embodiments, methods for in situ acid stimulation of a subterranean formation that contains a hydrocarbon reservoir comprise contacting the formation with an aqueous fluid that comprises (a) an ammonium salt capable of being oxidized to produce acid and (b) an oxidizing agent capable of oxidizing the ammonium salt, where the ammonium salt and oxidizing agent react to produce an acid.

Abstract: A method for reducing condensate in a subsurface formation is disclosed. The method comprises introducing a first reactant and a second reactant into the subsurface formation. The first reactant and the second reactant produce an exothermic reaction that increases temperature and pressure in the subsurface formation to greater than a dew point of the condensate. Increasing the temperature and pressure in the subsurface formation to greater than the dew point of the condensate vaporizes, and thereby reduces, condensate in the subsurface formation.

Abstract: A method of cementing an oil or gas well for abandonment comprises cutting the production tubing 6 above the production packer 8, setting a tubing plug 9 in the tubing and then cutting the tubing. A bridge plug may be installed at the level of the cut, which spans the full diameter of the well casing 3. An agitator assembly 20 comprising an agitator 24, packer 21 and burst sub 23, with a running tool fitted to the top, is run down the tubing on wire line. Cement is then injected into the tubing 6, which flows through the agitator assembly and causes the tubing to vibrate. The cement fills the tubing but also flows back up the A annulus between the casing and production tubing. Vibration of the tubing assists the formation of a good quality cement plug extending all around the annulus over a substantial length of the well.

Abstract: Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

Abstract: Asphaltene produced during the production of hydrocarbons in an underground reservoir may be reduced and decomposed by introducing into the underground reservoir a fluid having a catalyst of from about 3 to about 7% Ni with a magnesium oxide support or a catalyst of from about 15 to about 25% tungsten oxide with a zirconium oxide support or a mixture thereof. The viscosity of heavy oil within the underground reservoir is reduced in the presence of the catalyst.

Abstract: A composition and methods for setting a plug for well bores undergoing plugging and abandonment operations. Methods include placing a blocking device below the plug location and creating a void space above the blocking device; placing a heat resistant base plate above the blocking device and introducing nano-thermite clusters and expandable bismuth alloy pellets into the void space; igniting the thermite and cooling the melted alloy to form a permanent plug in the void space.

Abstract: Fracturing fluid compositions including a base fluid including a high TDS produced and/or flow back water, brackish water, RO reject water, clear brine, and mixtures thereof with or without added fresh water and systems, and methods for making and using same, where the method includes: (a) adding a first buffer to adjust the pH of a base fluid to an acidic pH, (b) adding a hydratable polymer or polymer slurry to the base fluid to form a hydratable polymer fracturing fluid, (c) adding a cross-linking composition to the hydratable polymer fracturing fluid to form a pre-cross-linked fracturing fluid, and (d) if needed, adding a second buffer to the pre-cross-linked fracturing fluid to adjust the pH of the pre-cross-linked fracturing fluid to form a viscosified fracturing fluid having a crosslinked structure.

Abstract: A portion of a wellbore is drilled in a subterranean formation, using a drilling string (140) disposed within a casing string (130) and extending through a cement retainer (150) disposed within the casing string. The drilling string can be retracted into the casing string to a location fully above the cement retainer, and subsequently the casing string can be cemented in the wellbore whereby maintaining the drilling string inside the casing in the wellbore.

Abstract: Method and systems for sealing a lost circulation zone of a subterranean well include extending a drill string into the subterranean well, the drill string having an ultraviolet system, an actuator, and a fluid flow path. The actuator is instructed to transmit an on signal to the ultraviolet system to switch the ultraviolet system to an on condition. In the on condition the ultraviolet system generates ultraviolet light directed towards the fluid flow path of the drill string. A loss circulation material is delivered into the fluid flow path of the drill string, the loss circulation material having an oligomer, a monomer, and a photo-initiator. The loss circulation material is exposed to the ultraviolet light to activate the loss circulation material. The loss circulation material is delivered to the lost circulation zone.

Abstract: A method of providing an optimal surfactant blend to improve waterflood efficiency comprises selecting candidate surfactant blends based on one or more of the following: a reservoir condition; information of a crude oil; information of an injection fluid; or information of a formation fluid, each candidate surfactant blends comprising at least two surfactants, one surfactant having a higher relative affinity for the crude oil than for the injection fluid and at least one surfactant having a higher affinity for the injection fluid than for the crude oil; evaluating phase behavior of the candidate surfactant blends to select surfactant blends that form a Winsor III system with the crude oil and the injection fluid at a reservoir temperature; and evaluating the selected surfactant blends in a porous media to select an optimal surfactant blend which achieves at least an additional 10% crude oil recovery after waterflood.

Abstract: Aqueous liquid which has been in contact with a subterranean geological formation, especially a hydrocarbon reservoir, is examined in order to detect or measure viscosifying polymer therein, by flowing a sample of the liquid through a constriction thereby causing extensional flow and alignment of any polymer molecules with the flow, and examining the solution for birefringence of aligned polymer molecules. The amount of birefringence is determined from intensity of light which has passed through the solution relative to intensity of the light source.

Abstract: A method of drilling and completing a wellbore in a subterranean formation comprises circulating an invert oil emulsion fluid in the subterranean formation; the invert oil emulsion fluid comprising an oil phase, an emulsifier, and an internal phase comprising an alcohol other than a polycyclicpolyetherpolyol with molecular weight in excess of 50,000 and a salt dissolved in the alcohol, wherein the alcohol and the salt are selected such that the salt has a solubility in the alcohol of greater than about 3 g/100 ml at 23° C.