Abstract: Mechanical quantities associated with a deformation force impacting a structure may be determined using one or more integrated computational elements. Methods for determining a mechanical quantity may comprise: optically interacting electromagnetic radiation with one or more integrated computational elements and a target area of a structure, the structure comprising a deformable material in an initial amount and a reference material in an initial amount within the target area; exposing the structure to a deformation force; determining a change in amount of the deformable material or the reference material within the target area, using the one or more integrated computational elements; and correlating the change in amount of the deformable material or the reference material within the target area to a mechanical quantity associated with the deformation force.

Abstract: Mechanical quantities associated with a deformation force impacting a structure may be determined using one or more integrated computational elements. Methods for determining a mechanical quantity may comprise: optically interacting electromagnetic radiation with one or more integrated computational elements and a target area of a structure, the structure comprising a deformable material in an initial amount and a reference material in an initial amount within the target area; exposing the structure to a deformation force; determining a change in amount of the deformable material or the reference material within the target area, using the one or more integrated computational elements; and correlating the change in amount of the deformable material or the reference material within the target area to a mechanical quantity associated with the deformation force.

Abstract: Compositions and methods for the treatment of siliceous materials (e.g., silica and/or other silicates) in subterranean applications are provided. In one embodiment, the methods comprise: providing a treatment composition comprising a base fluid, a catechol component, and an amine component; introducing the treatment composition into at least a portion of a subterranean formation comprising one or more siliceous materials; and allowing at least a portion of the treatment composition to contact at least a portion of the siliceous materials in the subterranean formation to dissolve at least a portion of the siliceous materials.

Abstract: Systems, methods and devices for analyzing a sample of fluid extracted from a hydrocarbon-producing geological formation to detect a quantitative amount of hydrogen sulfide or disclosed. The systems methods and devices involve including a scavenger within a sample compartment to react with the hydrogen sulfide therein. The concentration of hydrogen sulfide in the sample may be derived as a function of the amount of scavenger remaining in the sample after reaction with hydrogen sulfide, an amount of byproduct of a reaction between the scavenger and the hydrogen sulfide, or an amount of hydrogen sulfide as measured following a secondary reaction that releases the hydrogen sulfide from the scavenger.

Abstract: A method of treating a treatment zone of a well, the method comprising: (A) forming a treatment fluid comprising: (i) a continuous gas phase comprising a gas; and (ii) a surfactant, wherein the surfactant has the following characteristics: (a) a normal boiling point less than 500° F. (260° C.) without significant thermal decomposition; and (b) providing a dynamic surface tension of less than about 40 dynes/cm for a 0.1 wt % solution, or having an HLB (Griffin) in the range of about 2 to about 20, or both; wherein the surfactant is dispersed in the gas; and (B) introducing the treatment fluid into the treatment zone.

Abstract: Methods including providing a treatment fluid comprising: a gas; and a volatile surfactant dispersed in the gas, wherein the volatile surfactant has a normal boiling point of less than 260° C. without substantial thermal decomposition and a dynamic surface tension of less than about 40 dynes/cm for a 0.1% solution; and intermittently introducing the treatment fluid and an aqueous fluid into a treatment zone in a subterranean formation.

Abstract: A wellbore treatment fluid containing lost circulation materials and methods for using the treatment fluid, the fluid including a carrier fluid and nano-carbohydrate based sheets. The sheets may be folded or rolled into various cross-sectional surface area reducing configurations. The nano-carbohydrate based sheets may contain cellulose and or chitin materials. A method for utilizing the treatment fluid for creation or maintenance of a well includes forming or providing the treatment fluid and introducing the treatment fluid into a borehole.

Abstract: Packing fluids that include (a) an aqueous solvent, and optionally one or more water-miscible organic liquids; and (b) one or more organic cationic and/or alkali metal tungstates, molybdates, and/or silicates dissolved in the solvent are disclosed. The fluid may be substantially free of salts and esters of formic acid. The disclosure further relates to methods of making and using the packing fluids.

Abstract: Improved methods and additives for eliminating or reducing concentrations of hydrogen sulfide or soluble sulfide ions for use in subterranean formations and fluids are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising an oil-based liquid and a sulfide scavenging additive comprising one or more polyaliphatic amines and a catalyst comprising one or more quaternary ammonium salts; introducing the treatment fluid into at least a portion of a subterranean formation; and allowing the sulfide scavenging additive to interact with hydrogen sulfide or sulfide ions present in the treatment fluid.

Abstract: Fluids and methods of making and using the fluids that include, for example, well bore treatment fluids, kill fluids, packer fluids, thermal insulating fluids and the like that contain soluble weighting material. The fluids include: (a) an aqueous solvent such as water, and optionally one or more water-miscible organic liquids; and (b) one or more organic cationic tungstates, molybdates, and/or silicates dissolved in the solvent. In some cases, the fluids are substantially free of lithium (Li), sodium (Na), potassium (K), rubidium (Rb), cesium (Cs), and francium (Fr) salts and/or ions. The fluid may also be an oil-based emulsion including the aqueous-based fluid. Methods of making and using both the aqueous fluids and oil-based emulsions are also disclosed.

Abstract: Dual phase compositions for treating a hydrocarbon stream are disclosed, wherein the dual phase compositions are colloidal micellar solutions with an aqueous phase and an oil phase. Methods are also disclosed for reducing emulsions in a hydrocarbon stream by contacting the hydrocarbon stream with a dual phase composition.

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: The physical properties of a fluid may be used in deriving the compositional properties of the fluid, which may, in turn, be used to influence an operational parameters of a drilling operation. For example, a method may include drilling a wellbore penetrating a subterranean formation with a drilling fluid as part of a drilling operation; circulating or otherwise containing the drilling fluid in a flow path that comprises the wellbore; measuring at least one physical property of the drilling fluid at a first location and a second location along the flow path; deriving a compositional property of the drilling fluid at the first location and the second location based on the at least one physical property that was measured; comparing the compositional property of the drilling fluid at the first location and the second location; and changing an operational parameter of the drilling operation based on the comparison.

Abstract: Methods including providing a treatment fluid comprising a base fluid, a wettability altering surfactant, and a chelating agent, wherein the treatment fluid has a pH of at least about 5; introducing the treatment fluid into a subterranean formation; altering a wettability of the subterranean formation from oil-wet to either mixed-wet or water-wet with the wettability altering surfactant; and complexing metal ions in the subterranean formation with the chelating agent.

Abstract: Disclosed are systems and methods for monitoring drilling fluids. One system includes a flow path containing a fluid having at least one component present therein, and a movable housing having at least one optical computing device configured to move with the movable housing along a detection path, the at least one optical computing device including at least one integrated computational element (ICE) configured to optically interact with the fluid over the detection path, wherein the at least one ICE is configured to detect a characteristic of the at least one component and generate an output signal corresponding to the characteristic.

Abstract: Methods for resolving emulsions in a hydrocarbon stream by contacting the hydrocarbon stream with a demulsifying composition are disclosed. Demulsifying compositions for treating a hydrocarbon stream are also disclosed, wherein the demulsifying composition comprises at least one C4-C12 alkyl phenol-formaldehyde resin alkoxylate.

Abstract: Phospho-friction reducing agents may include phosphonates, thiophosphonates, and derivatives thereof. The phospho-friction reducing agents may be included in drilling fluids with oleaginous base fluids and used in methods that involve drilling a wellbore penetrating a subterranean formation. Further, the phospho-friction reducing agents may be useful at relatively low concentrations in the drilling fluids (e.g., about 0.001 v/v % to about 0.5 v/v % of the drilling fluid).

Abstract: Improved methods and additives for eliminating or reducing concentrations of hydrogen sulfide or soluble sulfide ions for use in subterranean formations and fluids are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising an oil-based liquid and a sulfide scavenging additive comprising one or more polyaliphatic amines and a catalyst comprising one or more quaternary ammonium salts; introducing the treatment fluid into at least a portion of a subterranean formation; and allowing the sulfide scavenging additive to interact with hydrogen sulfide or sulfide ions present in the treatment fluid.

Abstract: Improved methods and additives for eliminating or reducing concentrations of hydrogen sulfide or soluble sulfide ions for use in subterranean formations and fluids are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising a base liquid and a sulfide scavenging additive comprising one or more reducing sugars; introducing the treatment fluid into at least a portion of a subterranean formation; and allowing at least a portion of the sulfide scavenging additive to interact with hydrogen sulfide or sulfide ions present in the treatment fluid to produce a precipitate comprising one or more sulfur species.

Abstract: Methods of treating a subterranean formation including providing a treatment fluid comprising an oil-based fluid component and an oil-soluble weighting agent that comprises a metal, wherein the oil-soluble weighting agent has a density in the range of from about 1.1 g/cm3 to about 22 g/cm3; solubilizing the oil-soluble weighting agent in the oil-based fluid component of the treatment fluid, wherein the oil-soluble weighting agent increases the density of the oil-based fluid component of the treatment fluid; introducing the oil-based treatment fluid into a wellbore in a subterranean formation.