The present invention relates to a method for producing mineral oil from underground mineral oil deposits, in which an aqueous formulation comprising at least a mixture of alkyl ether carboxylate and corresponding alkyl ether alcohol, where the alkyl ether carboxylate has been prepared from the alkyl ether alcohol and the molar ratio in the mixture of alkyl ether carboxylate:alkyl ether alcohol is from 51:49 to 92:8, is injected through at least one injection well into a mineral oil deposit, where the deposit has a deposit temperature of 55° C. to 150° C., a crude oil having more than 20° API and a deposit water having more than 100 ppm of divalent cations, and crude oil is withdrawn through at least one production well from the deposit. The invention further relates to the preparation of the mixture and to a concentrate comprising the mixture.

The present invention relates to a milk-like friction reducer used in slick water fracturing and belongs to the technical field of oilfield chemicals. This friction reducer is obtained via free radical polymerization in water by using component A, component B and component C; wherein said component A is a mix of nonionic water-soluble monomers having carbon-carbon double bond; wherein said component B is a mix of water-soluble polymeric stabilizers obtained from monovalent cationic monomers; and wherein said component C is a mix of monovalent inorganic salts. The present invention is environmentally-friendly and easy to use. Its subsequent friction reducer is convenient to add on-the-fly and leads to no foaming without adding anti-foamer. Moreover, unlike other regular friction reducers, it is tolerant with various brines and compatible with common oilfield additives. The subject friction reducer can achieve an extent of friction reduction of greater than 70%.

Methods including preparing a treatment fluid comprising an aqueous base fluid, a gelling agent, and crosslinker-coated particulates, wherein the crosslinker-coated particulates are formed by at least partially coating a particulate with a stabilizing agent, and at least partially coating the particulate with a first crosslinking agent atop the stabilizing agent, wherein the stabilizing agent imparts a hydrophobic nature to the particulate when the stabilizing agent is at least partially coated onto the particulate; introducing the treatment fluid into a subterranean formation, and reacting the first crosslinking agent with the gelling agent in the treatment fluid so as to crosslink the gelling agent and suspend the crosslinker-coated particulates.

Nano-sized mixed metal oxide carriers capable of delivering a well treatment additive for a sustained or extended period of time in the environment of use, methods of making the nanoparticles, and uses thereof are described herein. The nanoparticles can have a formula of:

A/[M.sub.x.sup.1M.sub.y.sup.2M.sub.z.sup.3]O.sub.nH.sub.m

where x is 0.03 to 3, y is 0.01 to 0.4, z is 0.01 to 0.4 and n and m are determined by the oxidation states of the other elements, and M.sup.1 can be aluminum (Al), gallium (Ga), indium (In), or thallium (Tl). M.sup.2 and M.sup.3 are not the same and can be a Column 2 metal, Column 14 metal, or a transition metal. A is can be a treatment additive.

The invention relates to a novel sulfobetaine monomer and to a process for the preparation thereof, advantageously by reaction between a vinyl-amine compound and a vinyl-sulfonic acid compound, preferably in the presence of a solubilizing agent. The invention also relates to the (co)polymers obtained from this novel type of sulfobetaine monomer, and to the use thereof, for example as a flocculant, dispersing agent, thickening agent, absorbent agent or friction-reducing agent.

A polymer composition may include one or more monomeric units, with an internal crosslinker, internal breaker, scale control additive or a combination thereof.

Systems and methods for fracturing an interval of a subterranean formation to produce fluid from a reservoir through a wellbore. A treating fluid flows into the wellbore to create fractures in the formation. A flow constraint material is selectively flowed into the wellbore simultaneously with the treating fluid. A parameter of the formation is monitored to determine whether a formation system strain is within a range. When the formation system strain is out of the range, the flow of the flow constraint material is adjusted. The flow constraint material partially constrains the treating fluid from entering a fracture so as to at least partially redistribute the treating fluid to an another fracture or fractures.

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

Compositions and methods of fracturing including a hydrophobic rendered proppant or a proppant slurry and a fracturing fluid including an aqueous base fluid, a viscosifying agent or mixture of viscosifying agents, and an enhancing proppant suspending composition including an aldehyde, a mixture of aldehydes, a ketone, a mixture of ketones, or mixtures thereof, and optionally a crosslinking agent or a mixture of crosslinking agents.

Formation treatment compositions may include a surfactant and an aqueous acid solution or mixture. The surfactant may include one or more of C.sub.6-C.sub.20-fluoroalkylsulfonate, C.sub.6-C.sub.20-alkylarylsulfonate, C.sub.6-C.sub.20-alkylcycloalkylsulfonate, C.sub.6-C.sub.20-arylsulfate, C.sub.6-C.sub.20-alkylphosphonate, C.sub.6-C.sub.20-arylphosphonate, C.sub.6-C.sub.20-alkylpolyetherphosphate, C.sub.6-C.sub.20-alkylpolyetherphosphonate, C.sub.6-C.sub.20-alkylcarboxylate, C.sub.6-C.sub.20-arylcarboxylate, and polyoxyethyleneamine. In the formation treatment compositions, the surfactant may be configured to partially or fully adsorb on a carbonate formation to accelerate the partial dissolution of the formation. Methods of treating a formation may include introducing the formation treatment composition into a wellbore such that that the formation treatment composition contacts the formation.