A hydraulic fracking aqueous fluid, including: water; one or more soluble calcium salts; a carbonate ion generating compound; and one or more soluble zinc salts. A method for fracking an underground formation using the hydraulic fracking fluid.

Compositions of lost circulation materials and methods for using the same in subterranean formations can include introducing a treatment fluid into a wellbore penetrating at least a portion of a subterranean formation including a loss zone, the treatment fluid including an aqueous base fluid, at least one viscoelastic surfactant, at least one component selected from the group consisting of: a divalent salt, a metal salt, a metal oxide, and any combination thereof, and a lost circulation material; and allowing the treatment fluid to at least partially plug the loss zone.

The present disclosure relates to a gas hydrate inhibitor composition, comprising A) a compound according to formula (1) ##STR00001## wherein R1 is an alkyl group having from 1 to 5 carbon atoms; R2 is hydrogen or an alkyl group having from 1 to 5 carbon atoms; R3 is present or not as hydrogen and organic moieties having from 1 to 20 carbon atoms; R4 is selected from —(CH.sub.2).sub.t—, —[CH.sub.2—CHR.sup.6).sub.t]—, —(CH.sub.2—CHR.sup.6O).sub.u—(CH.sub.2).sub.t— and combinations thereof; R5 is an alkyl or alkenyl group having 4 to 22 carbon atoms; R6 is hydrogen or an alkyl group having from 1 to 4 carbon atoms; R7 is hydrogen or an alkyl group having from 1 to 4 carbon atoms; R8 is present or not as hydrogen or organic moieties having from 1 to 20 carbon atoms; t is 2, 3 or 4; u is an integer between 0 and 100; n is 0 or 1 m is 0 or 2 o is 0 or 2, p is 0 or 1 X.sup.− is an anion, and a synergistic cationic surfactant which is selected from quaternary benzyl ammonium salts having besides the benzyl group at least one C.sub.8-C.sub.18-alkyl group bound to the nitrogen atom.

An acid-generating fluid includes a thermally activated strong acid precursor. The thermally activated strong acid precursor can include a component selected from aldehydes, ketones, and combinations thereof, in combination with a precursor of a compound adapted to react to liberate sulfur dioxide; or it can include sulfur dioxide in combination with a precursor of a compound adapted to react to liberate a component selected from aldehydes, ketones, and combinations thereof.

A wellbore fluid may include an oleaginous fluid forming a continuous phase; a non-oleaginous fluid forming a discontinuous phase; at least one emulsifier stabilizing an emulsion of the non-oleaginous continuous phase within the oleaginous continuous phase; and at least one viscosifier dispersed into the oleaginous continuous phase in a concentration of at least 4 ppb; wherein upon subjecting the wellbore fluid to shear rate of at least 10,000 s-1, the emulsion is disrupted and the non-oleaginous fluid contacts the at least one viscosifier, thereby solidifying the wellbore fluid.

In a well in a subterranean formation, treatment fluids for time-released iron control are utilized. These treatment fluids contain a time-released form of a complexing agent, wherein the complexing agent forms an insoluble complex with iron. The time-released form prevents loss of the agent prior to delivery to the desired site and at the desired time(s). Methods for controlling iron in a well in a subterranean formation utilize these treatment fluids containing a time-released form of a complexing agent and these methods create insoluble complexes of the agent with the iron to control the iron from the formation and/or well.

In a well in a subterranean formation, treatment fluids for time-released iron control are utilized. These treatment fluids contain a time-released form of a complexing agent or reducing agent, wherein the agent forms a soluble product with iron. The time-released form prevents loss of the agent prior to delivery to the desired site and at the desired time(s). Methods for controlling iron in a well in a subterranean formation utilize these treatment fluids containing a time-released form of a complexing agent or reducing agent and these methods create soluble products when the agent interacts with the iron to control the iron from the formation and/or well.

Provided is a method for mitigating a lost circulation zone. The method may include providing a lost circulation treatment composition that may include an acid responsive polymer that may include at least one monomer, at least one comonomer, and at least one crosslinker; a carbonate-based solvent; and a carrier fluid that may include water. The method may also include introducing the lost circulation treatment composition into a wellbore within a subterranean formation, wherein the subterranean formation may include the lost circulation zone; placing the lost circulation treatment composition into the lost circulation zone, hydrolyzing the carbonate-based solvent to generate carbon dioxide, and causing the swelling (change of shape) of acid responsive polymer to mitigate the losses.

A method for treating hydrocarbons in a reservoir is provided. The method includes the steps of introducing a foaming surfactant solution and a foaming gas into the upper portion of a reservoir such that barrier foam bubbles form. The method includes introducing super/critical carbon dioxide such that a CO2 cap forms. The CO2 cap forms above a foam barrier positioned at an interface between the hydrocarbons to be treated in the reservoir and the CO2 cap. The foam barrier comprises aggregated barrier foam bubbles. The super/critical carbon dioxide is introduced into the reservoir at an injection rate that is greater than a pre-treatment critical gas injection rate. Hydrocarbons are recovered from a lower portion of the reservoir. The barrier foam bubbles that form are comprised of a foaming gas that has diminished solubility in aqueous solutions as compared with other gases, such as carbon dioxide.

A method of treating a well, comprising introducing a well treatment fluid into the well. The well treatment fluid includes an aqueous base fluid and a dewatering agent. The dewatering agent includes water, a demulsifying surfactant, and a polyamine polyether.