The present application describes compositions and methods for inhibiting acid corrosion.

A completion/stimulation/production fluid and injection mixture blend is disclosed. The blend may include an aqueous fluid, a polymer system and an injection mixture that includes a polyol, a natural sugar, an artificial sugar, or a combination thereof.

The present invention relates to a method for reducing or preventing the formation or activity of a corrosion-associated biofilm on a metal surface, wherein the method comprises contacting the metal surface with a liquid composition comprising biocidal preparation. The present invention also relates to a microbicidal composition comprising at least one alcohol, one liquid hydrocarbon, a bacteriophage immobilized on a magnetic nanocomposite, at least one phage releasing reagent and one stabilizer. The microbicide composition and method of the present invention reduces biofilms on surfaces, and consequently, reduces, mitigates, or eliminates MIC in internal surface of the oil transporting pipelines.

The present invention discloses a preparation method for the plant-based nano corrosion inhibition bactericide for oilfield, comprising the following steps: Step 1. Prepare the aloin liquid; Step 2. Stir the carbon nanotube, hydroxyethyl methacrylate and acrylic acid to react for 4 h at a constant temperature of 80° C. to get the carbon nanotube after fiber treatment, namely the modified carbon nanotube; Step 3. Mix the aloin liquid with imidazoline-ammonium-salt, add acetonitrile, and then add modified carbon nanotube, increase the temperature to 95° C. stir and react for 12 hours, and filter after naturally cooling down to room temperature and get the carbon nanotube loaded with bactericide; Step 4. Stir the carbon nanotube loaded with bactericide, diphenylmethane diisocyanate and polycaprolactone to react for 6 hours at a constant temperature of 95° C. and in the reaction process, continuously inject helium to get the target bactericide.

A method of reducing the viscosity of a crude oil, the method including adding to the crude oil (i) a surfactant compound including at least two hydrophobic groups wherein the resultant mixture has a water content of less than 10 vol %.

An aqueous solution is disclosed including water, an acid, a nitrogen-containing compound, and a functionalizing agent (FA), which can be a ketone, diketone, aldehyde, dialdehyde, organic acid, and combinations thereof. An additional aqueous solution is disclosed including water, an acid, and an acid neutralizing agent which can be a reaction product of at least a portion of the nitrogen-containing compound and the functionalizing agent. Methods of treating a formation are also disclosed including treating a formation fluidly coupled to a wellbore with an oilfield treatment fluid comprising either or both of the aqueous solutions.

The present technology relates to a process for enhancing hydrocarbon production from a shale formation. In particular, the present technology relates to a process wherein a treatment fluid comprising a water soluble delayed release carbonate-dissolving agent is introduced into the shale formation after or as part of a hydraulic fracturing process. The present technology also relates to a treatment fluid that can be used in such a process.

Scavenging chemicals used in mitigation treatments of hydrogen sulfide in hydrocarbon streams often continue to react and form polymers that foul the processing system. Disclosed herein are methods for determining if a scavenging chemical mitigator, or its reaction or degradation product, will polymerized during or after mitigation treatments. This information allows for the optimization of mitigation treatments that pre-emptively control or prevent polymer formation. Such pre-emption measures reduce the cost and time related to remedial actions to treat polymer-fouled equipment.

Described herein are methods for treating a subterranean formation penetrated by a wellbore with a retarded acidizing fluid containing an acid and an acid retarding agent, the concentrations of which are adjusted based on measured parameter values of the formation. Also described is a method for treating a subterranean formation by introducing an acid to the formation following the introduction of an acid retarding agent to the formation. Also described is a method for acid fracturing a subterranean formation including reducing the concentration of an acid retarding agent contained in a retarded acidizing fluid over the course of the acid fracturing operation.

Use of methyl glycine diacetic acid (MGDA) as additive in processes for recovering crude oil and/or gas from subterranean formations, wherein the MGDA is a mixture of L- and D-enantiomers of MGDA or salts thereof, said mixture containing an excess of the respective L-isomer, and the enantiomeric excess (ee) of the L-isomer is in the range of from 10% to 75% Preferably, the process is a processes of acidizing subterranean formations.