Compositions for treating a subterranean formation with a foamed system and corresponding methods
A method for treating a subterranean formation with a foamed system is disclosed. The method includes introducing a fracturing fluid into the formation. The fracturing fluid includes a first solution and a second solution. The first solution includes an ammonium containing compound. The second solution includes a nitrite containing compound. One or both of the solutions further include a foaming agent. The solutions are mixed within the formation to generate a nitrogen gas. The method further includes, allowing the compounds to generate nitrogen in the presence of the foaming agent to form a foam and generate the foamed system within the formation. Generation of the foamed system produces sufficient pressure from volumetric expansion to generate fractures in the formation. The fractures are held open with a proppant provided with the fracturing fluid to create a conductive path for production of fluids from the formation to the wellbore.
1. A method for treating a subterranean formation with a foamed system, the method comprising the steps of:
introducing a fracturing fluid into the subterranean formation at a pressure greater than a fracturing pressure of the subterranean formation to generate fractures in the subterranean formation, the fracturing fluid comprising a first solution and a second solution, in which:
the first solution comprises an ammonium containing compound comprising an ammonium salt,
the second solution comprises a nitrite containing compound comprising a nitrite salt,
one or both of the first solution and the second solution further comprises a foaming agent, and
the first solution and the second solution are mixed within the subterranean formation to thereby generate a nitrogen (N 2 ) gas; and
allowing the ammonium containing compound and the nitrite containing compound to generate nitrogen gas in the presence of the foaming agent to form a foam and generate the foamed system within the fractures,
where generation of the foamed system within the fractures diverts subsequently pumped fracturing fluid away from areas of the subterranean formation that have already been treated, and the fractures are held open with a proppant provided with the fracturing fluid to create a conductive path for production of fluids from the subterranean formation to the wellbore.
2. The method of claim 1 , in which the second solution comprises the foaming agent.
3. The method of claim 1 , in which the foam quality of the generated foam comprising the reaction products of the first solution and the second solution is at least 52%.
4. The method of claim 1 , in which the first solution and the second solution are introduced into the subterranean formation separately with:
the first solution introduced into the subterranean formation through a coiled tubing and the second solution introduced into the subterranean formation through a production tubing, or
the second solution introduced into the subterranean formation through the coiled tubing and the first solution introduced into the subterranean formation through the production tubing, or
the first solution introduced into the subterranean formation through a first coiled tubing and the second solution introduced into the subterranean formation through a second coiled tubing.
5. The method of claim 1 , in which the nitrite containing compound comprises NaNO 2 or and the ammonium containing compound comprises NH 4 Cl.
6. The method of claim 5 , in which the molar ratio of NaNO 2 to NH 4 Cl is from 1:1 to 3.1.
7. The method of claim 1 , in which the first solution and the second solution are introduced into the subterranean formation simultaneously as a single solution.
8. The method of claim 1 , in which the first solution and the second solution are introduced downhole of the wellbore into the subterranean formation simultaneously as a single solution.
9. The method of claim 8 , in which a temperature of the first solution and the second solution is at least 60° C.
10. The method of claim 1 , in which the foaming agent comprises a surfactant.
11. The method of claim 1 , in which the viscosity of the generated foam comprising the reaction products of the first solution and the second solution is greater than or equal to 2 centipoise (cP).
12. The method of claim 1 , in which one or both of the first solution and the second solution further comprises at least one fracturing fluid additive.
13. The method of claim 11 , in which one or both of the first solution and the second solution comprises at least one of a corrosion inhibitor, a friction reducer, a viscosifying agent, a gelling polymer, a gelling stabilizer, a crosslinker, a breaker, or a biocide.
14. The method of claim 1 , in which:
the first solution comprises the foaming agent in an amount of from 1 gallon per thousand gallons of solution (gpt) to 20 gpt;
the second solution comprises the foaming agent in an amount of from 1 gpt to 20 gpt; or
the first solution and the second solution each comprise a foaming agent in an amount of from 1 gpt to 20 gpt.