Foamed fluid compositions having high salinity using anionic surfactants and methods therefor
An effective amount of at least one anionic surfactant may be present within a high salinity foamed fluid composition in an effective amount to generate an IFT as low as 10 −3 mN/m. The anionic surfactant may be a sulfonate surfactant and/or a sulfate surfactant. The foamed fluid composition may be used to perform an operation, including but not limited to, a gas lift operation, a drilling operation, a completion operation, a stimulation operation, a fracturing operation, an injection operation, an enhanced oil recovery operation, and combinations thereof.
1. A method comprising:
introducing a foamed fluid composition within a subterranean reservoir wellbore of an oil or gas well and performing an operation with the foamed fluid composition;
where the foamed fluid composition comprises:
a base fluid, wherein the base fluid is an oil-based fluid or a water-based fluid selected from a group consisting of a drilling fluid, a completion fluid, a stimulation fluid, a fracturing fluid, a gas well deliquification fluid, a coiled tubing operations fluid, a recycled drilling fluid, a servicing fluid, a well clean-out fluid, a well intervention fluid, a capillary coiled tubing fluid and combinations thereof,
a gas,
at least one anionic surfactant having a hydrophobic chain of 12 to 24 carbon atoms, where the anionic surfactant is selected from the group consisting of sulfonate surfactants, sulfate surfactants, and combinations thereof, and
at least one second surfactant selected from the group consisting of cationic surfactants, nonionic surfactants, zwitterionic surfactants, and combinations thereof;
where the foamed fluid composition has a salinity equal to or greater than 30,000 ppm total dissolved solids; and unloading more than about 50 weight % of a pre-existing fluid within the subterranean reservoir wellbore with the foamed fluid composition in an amount of time of less than about 30 minutes.
2. The method of claim 1 , where the at least one anionic surfactant comprises a hydrophobic chain of from 20 to 24 carbon atoms, inclusive.
3. The method of claim 1 , where the at least one anionic surfactant comprises an internal olefin.
4. The method of claim 1 , where the at least one anionic surfactant is capable of generating an interfacial tension of between about 10 −1 mN/m and about 10 −3 mN/m.
5. The method of claim 1 , where the operation is conducted in an environment selected from the group consisting of a subterranean reservoir, a wellbore, a gas well, and combinations thereof.
6. The method of claim 1 , where the foamed fluid composition further comprises an additional component selected from the group consisting of solvents, winterizing agents, foam enhancers, biocides, shale stabilizers, paraffin dispersants, emulsion breakers, and combinations thereof.
7. The method of claim 1 , further comprising introducing the at least one anionic surfactant to the base fluid to form the foamed fluid composition prior to circulating the foamed fluid composition in the subterranean reservoir wellbore.
8. The method of claim 7 , where the introducing the at least one anionic surfactant occurs by a method selected from the group consisting of adding the at least one anionic surfactant to the base fluid, circulating the at least one anionic surfactant into the base fluid, continuously or intermittently injecting the at least one anionic surfactant into the base fluid, and combinations thereof.
9. The method of claim 7 , where the introducing the at least one anionic surfactant occurs in batch form or continuously.
10. The method of claim 1 where the operation is selected from the group consisting of a gas lift operation, a drilling operation, a completion operation, a stimulation operation, a fracturing operation, an injection operation, an enhanced oil recovery operation, and combinations thereof.
11. A method for unloading an oil or gas well within a subterranean oil-bearing formation comprising:
introducing a foamed fluid composition into a subterranean reservoir wellbore having a pre-existing fluid therein; where the foamed fluid composition comprises:
a base fluid, wherein the base fluid is selected from a group consisting of a drilling fluid, a completion fluid, a stimulation fluid, a fracturing fluid, a gas well deliquification fluid, a coiled tubing operations fluid, a recycled drilling fluid, a servicing fluid, a well clean-out fluid, a well intervention fluid, a capillary coiled tubing fluid and combinations thereof;
a gas;
at least one anionic surfactant selected from the group consisting of sulfonate surfactants, sulfate surfactants, and combinations thereof, where the at least one anionic surfactant comprises a C 12 -C 24 carbon chain and an internal olefin, and where the foamed fluid composition has a salinity equal to or greater than 30,000 ppm total dissolved solids; and
at least one second surfactant selected from the group consisting of cationic surfactants, nonionic surfactants, zwitterionic surfactants, and combinations thereof;
where the at least one anionic surfactant and the at least one second surfactant are present in an amount effective to foam the composition; and
displacing more than about 50 weight % of the pre-existing fluid within the subterranean reservoir wellbore, wherein the displacement of the pre-existing fluid occurs in an amount of time of less than about 30 minutes.