Injection of tailored water chemistry to mitigate foaming agents retention on reservoir formation surface
Compositions and methods for treating a subterranean formation. The compositions can include positively and negatively charged divalent ions and a total dissolved solids concentration between 2000 and 3000 ppm. In some implementations, the composition includes calcium and magnesium ions. In some implementations, the composition includes sodium, chloride, and bicarbonate ions. In some implementations, the composition includes iodide, phosphate, or borate ions, or any combination thereof. Methods for treating the subterranean formation can include flowing a first aqueous solution that includes sodium ions into the subterranean formation and flowing a second aqueous solution that has a lower salinity than the first aqueous solution into the subterranean formation, where the second aqueous solution includes positively charged divalent ions, negatively charged divalent ions, and a total dissolved solids concentration between 2000 and 30000 ppm.
1. A method of treating a subterranean formation, comprising:
flowing a first aqueous solution comprising sodium ions into the subterranean formation; and
flowing a second aqueous solution into the subterranean formation, wherein the second aqueous solution is a lower salinity than the first aqueous solution and wherein the second aqueous solution comprises
positively charged divalent ions,
negatively charged divalent ions,
500 to 1000 ppm of I − ions, PO 4 3− ions, BO 3 3− ions, or a combination thereof, and
a total dissolved solids concentration between 2000 and 30000 ppm.
2. The method of claim 1 , wherein flowing the first aqueous solution comprising sodium ions into the subterranean formation comprises flowing a first aqueous solution comprising at least 18,300 ppm sodium ions into the subterranean formation.
3. The method of claim 1 , wherein flowing the second aqueous solution into the subterranean formation comprises flowing 0.1 to 0.3 pore volumes of the second aqueous solution into the subterranean formation.
4. The method of claim 1 , further comprising flowing a surfactant into the subterranean formation.
5. The method of claim 4 , wherein flowing the surfactant into the subterranean formation comprises flowing 0.1 to 0.3 pore volumes of the surfactant into the subterranean formation.
6. The method of claim 4 , further comprising:
injecting a gas into the subterranean formation; and
generating a foam.
7. The method of claim 6 , wherein injecting a gas into the subterranean formation comprises injecting carbon dioxide gas, nitrogen gas, produced gas, or flue gas into the subterranean formation.
8. The method of claim 6 , further comprising:
injecting a gas into the subterranean formation; and
after injecting the gas into the subterranean formation, flowing water into the subterranean formation.
9. The method of claim 6 , further comprising displacing hydrocarbons in the subterranean formation.
10. The method of claim 1 , wherein the second aqueous solution further comprises:
900 to 1000 ppm Na + ions;
30 to 300 ppm Ca 2+ ions;
100 to 1200 ppm Mg 2+ ions;
200 to 4000 ppm SO 4 2− ions;
1000 to 20000 ppm Cl − ions; and
5 to 100 ppm HCO 3 − ions.
11. The composition of claim 1 , wherein the second aqueous solution comprises diluted seawater.
12. A method of treating a subterranean formation, comprising:
contacting the subterranean formation with a first aqueous solution containing sodium ions;
contacting the subterranean formation with 0.1 to 0.3 pore volumes of a second aqueous solution, wherein the second aqueous solution is a lower salinity than the first aqueous solution and wherein the second aqueous solution comprises
positively charged divalent ions,
negatively charged divalent ions,
500 to 1000 ppm of I − ions, PO 4 3− ions, BO 3 3− ions, or a combination thereof,
and a total dissolved solids concentration between 2000 and 30000 ppm;
contacting the formation with 0.1 to 0.3 pore volumes of a surfactant;
injecting a gas into the formation; and
generating a foam.
13. The method of claim 12 , wherein the second aqueous solution further comprises:
900 to 1000 ppm Na + ions;
30 to 300 ppm Ca 2+ ions;
100 to 1200 ppm Mg 2+ ions;
200 to 4000 ppm SO 4 2− ions;
1000 to 20000 ppm Cl − ions; and
5 to 100 ppm HCO 3 − ions.
14. The composition of claim 12 , wherein the second aqueous solution comprises diluted seawater.
15. The composition of claim 12 , wherein injecting a gas into the subterranean formation comprises injecting carbon dioxide gas, nitrogen gas, produced gas, or flue gas into the subterranean formation.
16. The composition of claim 12 , further comprising:
injecting a gas into the subterranean formation; and
after injecting the gas into the subterranean formation, flowing water into the subterranean formation.
17. The composition of claim 12 , further comprising displacing hydrocarbons in the subterranean formation.
18. The method of claim 12 , wherein:
the second aqueous solution further comprises:
diluted seawater;
900 to 1000 ppm Na + ions;
30 to 300 ppm Ca 2+ ions;
100 to 1200 ppm Mg 2+ ions;
200 to 4000 ppm SO 4 2− ions;
1000 to 20000 ppm Cl − ions; and
5 to 100 ppm HCO 3 − ions;
injecting a gas into the subterranean formation comprises injecting carbon dioxide gas, nitrogen gas, produced gas, or flue gas into the subterranean formation; and
the method further comprises displacing hydrocarbons in the subterranean formation.