Methods of sealing a subsurface formation with saudi arabian volcanic ash
A method of sealing a water-bearing subsurface formation includes introducing an activation solution including an aqueous solution, Na 2 SiO 3 , NaOH, and one or both of CaCO 3 or Mn 3 O 4 into the wellbore. The method further includes introducing Saudi Arabian volcanic ash into the wellbore. The Saudi Arabian volcanic ash comprises SO 3 , CaO, SiO 2 , Al 2 O 3 , Fe 2 O 3 , MgO, and K 2 O. The method further includes allowing the Saudi Arabian volcanic ash to contact the activation solution in the wellbore, thereby forming a geopolymer barrier between the wellbore and the water-bearing subsurface formation and sealing the water-bearing subsurface formation.
1. A method of sealing a water-bearing subsurface formation comprising:
introducing an activation solution comprising an aqueous solution, Na 2 SiO 3 (sodium silicate), NaOH (sodium hydroxide), and one or both of CaCO 3 (calcium carbonate) or Mn 3 O 4 (manganese oxide) into a wellbore;
introducing Saudi Arabian volcanic ash into the wellbore, in which:
introducing Saudi Arabian volcanic ash into the wellbore comprises introducing an ash solution comprising an aqueous solution and Saudi Arabian volcanic ash;
the aqueous solution comprises deionized water, tap water, fresh water, salt water, natural or synthetic brine, municipal water, formation water, produced water, well water, filtered water, distilled water, sea water, or combinations of these;
the ash solution comprises from 30 to 60 wt. % Saudi Arabian volcanic ash; and
the Saudi Arabian volcanic ash comprises SO 3 , CaO, SiO 2 , Al 2 O 3 , Fe 2 O 3 , MgO,
and K 2 O; and
allowing the Saudi Arabian volcanic ash to contact the activation solution in the wellbore, thereby forming a geopolymer barrier between the wellbore and the water-bearing subsurface formation and sealing the water-bearing subsurface formation.
2. The method of claim 1 , further comprising reducing water cut by sealing the water-bearing subsurface formation.
3. The method of claim 2 , further comprising:
producing hydrocarbons from a reservoir, where the hydrocarbon production has a first water cut, before introducing the activation solution and the Saudi Arabian volcanic ash;
stopping hydrocarbon production from the reservoir before introducing the activation solution and the Saudi Arabian volcanic ash;
resuming hydrocarbon production from the reservoir after forming the geopolymer barrier, where the hydrocarbon production has a second water cut, and the second water cut is less than the first water cut.
4. The method of claim 1 , in which the activation solution comprises from 10 to 90 wt. % CaCO 3 or Mn 3 O 4 .
5. The method of claim 1 , in which the activation solution comprises from 25 to 50 wt. % Na 2 SiO 3 and 15 to 35 wt. % NaOH.
6. The method of claim 1 , in which the Na 2 SiO 3 has a ratio of Na 2 O to SiO 2 of from 0.250:1 to 0.350:1.
7. The method of claim 1 , in which the activation solution comprises SiO 2 in an amount of from 2 to 4 times the amount of Al 2 O 3 present in the Saudi Arabian volcanic ash by weight.
8. The method of claim 1 , in which the activation solution comprises a pH of from 11.6 to 13.0.
9. The method of claim 1 , in which the Saudi Arabian volcanic ash has a particle size of from 20 to 30 μm.
10. The method of claim 1 , in which the Saudi Arabian volcanic ash is free of TiO 2 .
11. The method of claim 1 , in which the Saudi Arabian volcanic ash comprises from 40 wt. % to 50 wt. % SiO 2 and from 10 wt. % to 20 wt. % Al 2 O 3 .
12. The method of claim 1 , in which the Saudi Arabian volcanic ash comprises:
from 0.05 wt. % to 0.2 wt. % SO 3 ;
from 5 wt. % to 10 wt. % CaO;
from 40 wt. % to 50 wt. % SiO 2 ;
from 10 wt. % to 20 wt. % Al 2 O 3 ;
from 10 wt. % to 15 wt. % Fe 2 O 3 ;
from 5 wt. % to 10 wt. % MgO; and
from 0.5 wt. % to 5 wt. % K 2 O.
13. The method of claim 1 , in which the ash solution further comprises one or more additives selected from the group consisting of dispersants, fluid loss control agents, retarders, expansion additives, antifoaming agents, stabilizers, accelerators, extenders, weighting agents, lost circulation control agents, surfactants, gypsum, hematite, manganese tetraoxide, silica flour, and silica sand.
14. The method of claim 1 , in which the geopolymer barrier has a compressive strength of from 1300 to 1500 psi.
15. The method of claim 1 , in which the geopolymer barrier has a ratio of Na 2 SiO 3 combined with NaOH to Al 2 O 3 ranges from 0.5:1.0 to 9.0:1.0.
16. The method of claim 1 , in which the geopolymer barrier comprises a sodium aluminosilicate hydrate.
17. The method of claim 16 , in which the sodium aluminosilicate hydrate comprises a formula of:
Na n [(—SiO 2 ) z —AlO 2 ] n .y H 2 O, where n represents a degree of polymerization ranging 1 to 50 and z represents an amount of silicate ranging from 2 to 10.
18. The method of claim 16 , in which the sodium aluminosilicate hydrate has a structure of:
19. A method of sealing a water-bearing subsurface formation comprising:
introducing an activation solution comprising an aqueous solution, Na 2 SiO 3 (sodium silicate), NaOH (sodium hydroxide), and one or both of CaCO 3 (calcium carbonate) or Mn 3 O 4 (manganese oxide) into a wellbore;
introducing Saudi Arabian volcanic ash into the wellbore, in which:
the Saudi Arabian volcanic ash comprises:
from 0.05 wt. % to 0.2 wt. % SO 3 ;
from 5 wt. % to 10 wt. % CaO;
from 40 wt. % to 50 wt. % SiO 2 ;
from 10 wt. % to 20 wt. % Al 2 O 3 ;
from 10 wt. % to 15 wt. % Fe 2 O 3 ;
from 5 wt. % to 10 wt. % MgO; and
from 0.5 wt. % to 5 wt. % K 2 O; and
the Saudi Arabian volcanic ash is free of TiO 2 ; and
allowing the Saudi Arabian volcanic ash to contact the activation solution in the wellbore, thereby forming a geopolymer barrier between the wellbore and the water-bearing subsurface formation and sealing the water-bearing subsurface formation.