An additive composition for improving one or more cold temperature properties in oil-based fluids is provided. One additive composition may include a first additive component selected from at least one alcohol ethoxylate, at least one amine ethoxylate, at least one ethylene oxide/propylene oxide copolymer, or a combination thereof, wherein the first additive component has an HLB ranging from about 4 to about 10. The additive composition may also include a second additive component selected from at least one alcohol, propylene glycol, at least one alcohol ethoxylate, or a combination thereof, wherein the second additive component has a total number of carbons from about 2 to about 30 carbons and a degree of ethoxylation is from zero to about 10.

Lost circulation particles are commonly used in drilling and/or cementing operations to prevent fluid loss to a subterranean formation. Lost circulation fluids and methods of drilling and/or cementing operations may also use petroleum coke lost circulation particles composed of fluid coke and/or flexicoke material. Such petroleum coke lost circulation particles may have improved transport into wellbores because of their lower density compared to traditional lost circulation material and may produce fewer fines that can interfere with lost circulation efficacy.

A composition that includes a polymer-grafted graphene particle and aqueous-based drilling fluid is provided. At least one side of the graphene particle comprises a grafted polymer. A method of using an aqueous-based drilling fluid is also provided. The method includes introducing the aqueous-based drilling fluid into a wellbore and circulating the aqueous-based drilling fluid during drilling operations. The drilling fluid includes a polymer-grafted graphene particle and aqueous-based drilling fluid. At least one side of the graphene particle comprises a grafted polymer. The aqueous-based drilling fluid includes a range of from about 0.01 ppb to 10 ppb of the polymer-grafted graphene particle.

A composition that includes a polymer-grafted graphene particle and aqueous-based drilling fluid is provided. At least one side of the graphene particle comprises a grafted polymer. A method of using an aqueous-based drilling fluid is also provided. The method includes introducing the aqueous-based drilling fluid into a wellbore and circulating the aqueous-based drilling fluid during drilling operations. The drilling fluid includes a polymer-grafted graphene particle and aqueous-based drilling fluid. At least one side of the graphene particle comprises a grafted polymer. The aqueous-based drilling fluid includes a range of from about 0.01 ppb to 10 ppb of the polymer-grafted graphene particle.

An example CO.sub.2 monitoring systems is configured for monitoring levels of CO.sub.2 in a wellbore. A CO.sub.2 monitoring system may include one or more laser monitoring tools. A laser monitoring tool may include an optical element to output a laser beam, a detector to receive the laser beam, a first chamber housing the optical element and detector, and a second chamber including an inlet and an outlet receive and release, respectively, wellbore fluid. The first chamber may be in fluid connection with second chamber via a gas permeable membrane. Gas may permeate from second chamber into first chamber. Gas in the first chamber is subjected to a laser beam. Absorption of light by the gas is measured, and content of gas is determined based at least in part on the amount of light absorption by the gas.

A method and drilling fluid additive for reducing severe fluid losses in a well, comprising a combination of granular scrap tire particles and polymer adhesive molded into a cone shape. Once in the severe loss zone, a plurality of LCMs wedge into the formation fractures and seal off the severe loss zone.

A method of detecting an amine-based additive in a wellbore servicing fluid (WSF) comprising contacting an aliquot of WSF with an amine detector compound and an aqueous salt solution to form a detection solution; wherein the aqueous salt solution comprises an inorganic salt and organic carboxylate salt; wherein the WSF comprises the amine-based additive; and wherein the detection solution is characterized by at least one absorption peak wavelength in the range of 380-760 nm; detecting an absorption intensity for detection solution at a wavelength within about ±20% of the at least one absorption peak wavelength; comparing the absorption intensity of detection solution at the wavelength within about ±20% of the at least one absorption peak wavelength with a target absorption intensity of amine-based additive to determine the amount of amine-based additive in WSF; and comparing the amount of amine-based additive in WSF with a target amount of amine-based additive.

A method of detecting an amine-based additive in a wellbore servicing fluid (WSF) comprising contacting an aliquot of WSF with an amine detector compound and an aqueous salt solution to form a detection solution; wherein the aqueous salt solution comprises an inorganic salt and organic carboxylate salt; wherein the WSF comprises the amine-based additive; and wherein the detection solution is characterized by at least one absorption peak wavelength in the range of 380-760 nm; detecting an absorption intensity for detection solution at a wavelength within about ±20% of the at least one absorption peak wavelength; comparing the absorption intensity of detection solution at the wavelength within about ±20% of the at least one absorption peak wavelength with a target absorption intensity of amine-based additive to determine the amount of amine-based additive in WSF; and comparing the amount of amine-based additive in WSF with a target amount of amine-based additive.

Methods of capturing carbon dioxide in a wellbore can include installing a sealing element in the wellbore. The sealing element swells in the presence of carbon dioxide and can be used for capturing the carbon. The sealing element can include a carbon-swelling material, such as a carbon-swelling polymers, metal-based materials, or combinations of elastomeric polymers and metal-based materials. The sealing element can also include combinations of different carbon-swelling materials, fillers or other compounds, and materials that are not carbon swellable. The sealing element can create a seal, form an anchor, or create a seal and form an anchor in the wellbore after swelling.

A system for producing fluids from a wellbore extending from a well surface to a fluid-producing formation has a Y-tool installed in fluid communication with the tubing string placed in the wellbore. A pump, which may be an electric submersible pump (ESP), is installed in the Y-tool for lifting fluids from the formation to the surface. A blanking plug is positioned in the tubing string between the upper and lower connections of the Y-tool. A flushing port extends through a wall of the tubing string, positioned above and near the upper end of the blanking plug when in its operating position, and a flushing tube is located in the annular space between the tubing string and the wellbore casing. The flushing tube is in fluid communication with the flushing port and extends from the flushing port to the well surface. Flushing fluid is pumped downhole through the flushing tube to agitate and disperse any accumulated sand, scale and other particulate matter on top of the blanking plug.