Abstract: Water solvated polymeric dyes and polymeric tandem dyes having a blue excitation spectrum are provided. The polymeric dyes are conjugated polymers that can include a thiophene-containing co-monomer. The polymeric tandem dyes further include a signaling chromophore covalently linked to the conjugated polymer in energy-receiving proximity therewith. Also provided are labelled specific binding members that include the subject polymeric dyes. Methods of evaluating a sample for the presence of a target analyte and methods of labelling a target molecule in which the subject polymeric dyes find use are also provided. Systems and kits for practicing the subject methods are also provided.

Abstract: Controlled release particles may include stimuli-responsive coatings on porous particles to allow for controlled release of a material in the pores of the porous particles. For example, a composition may comprise: a porous particle; a material in pores of the porous particle; and a coating bonded to a surface of the porous particle, wherein the coating comprises a multi-urethane compound capable of reversibly converting between a condensed state and an expanded state upon exposure to a stimuli.

Abstract: Halite scales in an oilfield brine that has a potential for halite scaling can have halite scale formation inhibited or prevented by adding an effective amount of an additive, where the additive contains at least one non-water-soluble quaternary ammonium compound and at least one organic solvent. The quaternary ammonium compound may be benzyl-alkyldimethyl ammonium chloride, where the alkyl group has from 2 to 30 carbon atoms. The organic solvent may be one or more alcohol or glycol.

Abstract: Disclosed is a gas hydrate inhibitor composition comprising an amphiphile by a linking moiety, the amphiphile having of the general formula (1) [R5-L-N(R1)(R2)(R3)]+X???(1) wherein each of R1 and R2 is an alkyl group having from 1 to 5 carbon atoms; or wherein the nitrogen atom and the R1 and R2 groups together form a heterocyclic group; R3 is present or not as hydrogen or an alkyl group having from 1 to 8 carbon atoms L is a linking moiety comprising a hydrocarbyl group having at least 2 adjacent carbon atoms, at least one heteroatom selected from nitrogen and oxygen, R5 is a hydrocarbyl group having from 6 to 22 carbon atoms; and X? is present as an anion when R3 is present; and a cationic surfactant which is selected from quaternary benzyl ammonium salts and a method of using the gas hydrate inhibitor composition.

Abstract: Methods and compositions for performing a sealing operation in a wellbore. An example method introduces a sealant composition into the wellbore while the sealant composition is under shear. The sealant composition comprises a thixotropic material, a conformance gel system, and an aqueous base fluid. The sealant composition is placed into a target location, and applied shear is reduced to the sealant composition when in the target location thereby allowing the sealant composition to thicken in the target location. Fluid flow across the target location is reduced by a fluid seal formed by the thickened sealant composition.

Abstract: A pH-sensitive temporary plugging agent and its preparation method, and the use thereof in exploitation of a low-permeability oil reservoir are disclosed. The temporary plugging agent is prepared by raw materials including, in percentages by mass, 3-8% of carboxymethyl chitosan, 0.2-0.7% of gelatin, 0.1-0.6% of an initiator, 5-15% of a toughener, and a balance of water, wherein the initiator is a solution of AgNO3 in ammonia water having a concentration of 0.1-0.3 mol/L, and the toughener is a carboxyl-terminated hyperbranched polyester.

Abstract: Disclosed are compositions and methods for use in oil and gas operations.

Abstract: Wellbore fluid compositions may include an oleaginous base fluid; and a polymeric rheology modifier incorporating a polar comonomer at a percent by weight (wt %) in the range of 1 wt % to 20 wt %; wherein the low shear rate viscosity (LSRV) of the wellbore fluid measured by FANN 35 rheometer at 3 rpm and 150° F. is in the range of 8 to 12. Methods may include emplacing a wellbore fluid in a wellbore, wherein the wellbore fluid comprises an oleaginous base fluid and a polymeric rheology modifier incorporating a polar comonomer at a percent by weight (wt %) in the range of 1 wt % to 50 wt %; wherein the low shear rate viscosity (LSRV) of the wellbore fluid is in the range of 8 to 12.

Abstract: A composition including: a lignin sulfonic acid-based compound and a water-soluble compound; a lignin derivative that is a reaction product of the lignin sulfonic acid-based compound with an aromatic water-soluble compound; or the lignin sulfonic acid-based compound, the water-soluble compound, and the lignin derivative. The composition is a granular product or a liquid product.

Abstract: A nanographene, a preparation method thereof, and uses thereof are disclosed. The method of preparing the nanographene includes the steps: (1) carrying out a first reaction by contacting a raw material graphite and a first oxidizing agent with an intercalating agent to obtain a modified graphite; (2) performing a second reaction by contacting the modified graphite and an acid with a second oxidizing agent to obtain a graphene pre-product; and (3) subjecting the graphene pre-product to an air-flow exfoliation to prepare a nanographene. An oil-based drilling fluid containing the nanographene produced by the method is also disclosed.

Abstract: The present disclosure relates to subterranean formation operations and, more particularly, to embedded treatment fluid additives for use in subterranean formation operations. The embedded treatment additives may comprise an aqueous-soluble downhole reactive material embedded in a crosslinked polymeric solution to delay the reactivity of the aqueous-soluble downhole reactive material, thereby forming the embedded treatment additive, wherein the aqueous-soluble downhole reactive material is a solid.

Abstract: A method and system for corrosion control and scale control in water supply for injection, including specifying a corrosion inhibitor for squeeze treatment of a water supply well, specifying a scale inhibitor that can form a complex with the corrosion inhibitor, pumping the corrosion inhibitor and the scale inhibitor through a wellbore of the water supply well into an aquifer in a subterranean formation, forming the complex of the corrosion inhibitor and the scale inhibitor, and pumping water from the water supply well to an injection well for injection, the water including the scale inhibitor released from the complex in the aquifer and the corrosion inhibitor released from the complex in the aquifer.

Abstract: A surfactant of formula (I) wherein each of R1 and R2 are independently a hydrogen, an optionally substituted alkyl, an optionally substituted cycloalkyl, or an optionally substituted arylalkyl, R3 and R4 are independently an optionally substituted alkyl, an optionally substituted cycloalkyl, or an optionally substituted arylalkyl, x is an integer in a range of 2-8, y is an integer in a range of 1-15, z is an integer in a range of 4-10, n is an integer in a range of 2-5, and A is one of a carboxybetaine group, a sulfobetaine group, or a hydroxy sulfobetaine group. An oil and gas well servicing fluid containing the surfactant and methods of servicing an oil and gas well are also described.

Abstract: A method of well treatment may include: providing a polymer; correlating performance of the polymer to a least one physical property of the polymer; and preparing a treatment fluid comprising the polymer.

Abstract: A method of inhibiting shale formation during water-based drilling of subterranean formations include s introducing a shale inhibitor to the subterranean formation during the water-based drilling, the shale inhibitor comprising a cationic polymer comprising repeating units of [A-B]. A is a substituted benzene or a substituted triazine of formula (2). B is a N-containing heterocycle. The cationic polymer and a method of making the cationic polymer are also described.

Abstract: A drilling fluid composition comprising a base fluid, and a shale inhibitor including an ultra-high molecular weight branched block copolymer having the following structure, where monomer A is an anionic monomer, monomer B is a hydrophilic monomer, monomer C is an anionic monomer, monomer D is a crosslinker-divinyl monomer, and —SSCZ ground being a terminal RAFT agent.

Abstract: A drilling fluid composition comprising a base fluid, and a drag reducing agent including an ultra-high molecular weight branched block copolymer having the following structure, where monomer A is an anionic monomer, monomer B is a hydrophilic monomer, monomer C is an anionic monomer, monomer D is a crosslinker-divinyl monomer, and -SSCZ ground being a terminal RAFT agent.

Abstract: Techniques for drilling wellbores are described. The techniques include a) introducing a drilling fluid composition into a borehole defined by a formation; b) introducing a thinner composition including at least one tannin and at least one metal salt into the borehole; and c) contacting the thinner composition and the drilling fluid composition in the borehole, wherein the at least one tannin and at least one metal salt are not complexed ex situ. The at least one metal salt includes at least one copper salt, at least one zinc salt, or both at least one copper salt and at least one zinc salt.

Abstract: An drilling mud composition is described, which includes an aqueous base fluid, a viscosifier, and a weighting material. The drilling mud composition also includes an anti-sagging agent that comprises a dimethylamino methyl ester, such as methyl 5-(dimethylamino)-2-methyl-5-oxopentanoate. The anti-sagging agent may be used to prevent barite sagging, where barite is used as a weighting material. Small amounts of the anti-sagging agent may be used to maintain a low sag factor while drilling, and without causing unwanted increases in viscosity. The anti-sagging agent is effective for both vertical and inclined wellbores.

Abstract: A method of forming a barrier to overcome lost circulation in a subterranean formation. The method includes injecting a polymer-sand nanocomposite into one or more lost circulation zones in the subterranean formation where the polymer-sand nanocomposite is formed from sand mixed with a polymer hydrogel. Further, the polymer hydrogel includes a hydrogel polymer, an organic cross-linker, and a salt. The sand additionally comprises a surface modification. The associated method of preparing a polymer-sand nanocomposite lost circulation material for utilisation in forming the barrier is provided.