Pitting corrosion of stainless steel occurs in solutions of organic acid, such as tartaric acid, in an electrolyte solution with methanol. However, methanolic solutions containing at least one organic halide and at least one organic hydroxyacid and some water provide reduced pitting corrosion of stainless steel. The organic hydroxyacid may be a hydroxy acid containing 2 to 10 carbon atoms with at least one hydroxyl group and at least one carboxylic acid group, in a non-limiting example, glycolic acid. The pH of the methanolic solution may range from about 3.5 to about 8.

The present disclosure provides water-based well treatment fluids for use in treating subterranean formations to prevent swelling and/or migration of fines. The water-based well treatment fluid contains an aqueous continuous phase, a clay stabilizing agent consisting of an alkylated polyetheramine and a weighting material. In addition to inhibiting swelling and/or migration, the water-based well treatment fluids are thermally stable, are toxicologically safe, and have exceptional handling properties.

A subsea fluids storage facility comprises a tank (11) for holding and separating fluids which is equipped with ballast capacity (14) and a separable base (12) to be deployed upon the seabed in shallow or deep water, and the storage facility is connectable to a surface production facility, especially a buoy (24) for processing fluids. In deep water the tank (11) is held at a depth above the base (12) for temperature controlled stabilization of produced oil in the tank (11).

A method of treating a subterranean formation. The method may include providing a well treatment including a treatment complex formed of a treatment agent encapsulated, entrapped, or embedded in a polysaccharide, introducing the treatment complex into a wellbore through a subterranean formation, and allowing the treatment complex to release the treatment agent over a release time period. The method may include allowing the treatment complex to release the treatment agent after a delay time period from the introduction of the treatment complex into the wellbore.

Copolymers having General Formula (I):

##STR00001##

in which R.sup.1, R.sup.2, and R.sup.3 are chosen from C.sub.1 to C.sub.30 aliphatic groups, R.sup.4 is chosen from divalent C.sub.4 to C.sub.7 linear aliphatic groups and divalent C.sub.4 to C.sub.7 linear heteroaliphatic groups, optionally substituted with one or more C.sub.1-C.sub.6 linear aliphatic groups, C.sub.1-C.sub.6 branched aliphatic groups, or combination thereof, R.sup.5, R.sup.6, and R.sup.7 are each independently chosen from methyl or hydrogen, x is chosen from 0 to 0.8, y is chosen from 0 to 0.8, when y is 0, x is greater than 0, and when x is 0, y is greater than 0, and z is chosen from 0.1 to 0.9. The summation of x, y, and z equals 1. Methods for inhibiting formation of clathrate hydrates in a fluid capable of forming the clathrate hydrates, including contacting the fluid with at least one copolymer of General Formula (I).

Copolymers having General Formula (I):

##STR00001##

in which R.sup.1 and R.sup.3 are chosen from divalent C.sub.4-C.sub.7 aliphatic groups and divalent C.sub.4-C.sub.7 heteroaliphatic groups, optionally substituted with one or more C.sub.1-C.sub.6 aliphatic groups, heteroatoms independently chosen from O, N, and S, or combination thereof, where the divalent C.sub.4-C.sub.7 heteroaliphatic groups of R.sup.1 and R.sup.3 include one or two heteroatoms independently chosen from O, N, and S, and the maximum number of heteroatoms in R.sup.1 or R.sup.3 is two, R.sup.2 is chosen from Q.sup.1 and Q.sup.2, x is a molar fraction range chosen from 0.1 to 0.9, y is a molar fraction range chosen from 0.1 to 0.9, and z is a molar fraction range chosen from 0 to 0.8, where the summation of x, y, and z equals 1. Methods for inhibiting formation of clathrate hydrates include contacting a fluid with at least one copolymer of General Formula (I).

A system and method for delivering heat to a fluid in a fluid production pipeline. Particles are injected into a line adjacent the fluid production pipeline. The particles include a microencapsulated liquid exothermic phase change material configured to undergo a phase change by solidification and release heat at a selected temperature. The released heat is transferred to the fluid production pipeline.

This disclosure relates to anti-agglomerant low dosage hydrate inhibitors that can inhibit the formation of hydrate agglomerants and/or plugs. The anti-agglomerant low dosage hydrate inhibitors may be surfactants. The hydrate inhibitors may be used for inhibiting, retarding, mitigating, reducing, controlling and/or delaying formation of hydrocarbon hydrates, agglomerants of hydrates, and/or plugs. The hydrate inhibitors may be applied to prevent, reduce, and/or mitigate plugging of conduits, pipes, transfer lines, valves, and other places or equipment where hydrocarbon hydrate solids may form. The hydrate inhibitors may be cationic ammonium surfactants having an ionizable secondary amine.

A lean MEG stream having a first pH level is contacted with a CO.sub.2-rich gas stream to yield a lean MEG product having a second different and lower pH level preferably in a range of 6.5 to 7.0. The system and method can be readily incorporated into a slipstream MEG recovery package, with a source of the lean MEG stream being a MEG regeneration section of the package. The CO.sub.2-rich gas could be a vented CO.sub.2 stream from the MEG reclamation section of the package. Unlike hydrochloric and acetic acid overdosing, CO.sub.2 overdosing of the lean MEG stream does not lead to rapid acidification of the lean MEG product to be stored or injected.

A method for wellbore treatment. The method including preparing an encapsulated treatment agent via polymerization, feeding the encapsulated treatment agent into the wellbore, delivering the encapsulated treatment agent to a desired depth within a formation in the wellbore, activating an acoustic or an electromagnetic source at the desired depth within the formation, and generating an acoustic field or an electromagnetic field. The acoustic field or electromagnetic field activates the encapsulant thereby releasing the treatment agent into the wellbore and a desired depth.