Water-based drilling fluid with cyclodextrin shale stabilizer
Well fluids and methods are provided that can be used for stabilizing a shale formation, especially during drilling of a well into or through a shale formation. The well fluids include: (i) a continuous water phase; (ii) a viscosity-increasing agent, wherein the viscosity-increasing agent comprises water-soluble hydrophilic polymer; (iii) a fluid loss control agent; and (iv) a cyclodextrin-based compound. The methods of drilling include the steps of: (A) introducing the well fluid into a zone of a subterranean formation; and (b) drilling the zone.
1. A method of drilling a zone of a well, the method comprising the steps of:
(A) introducing a water-based drilling fluid into the zone, the water-based drilling fluid comprising:
(i) a continuous water phase;
(ii) a viscosity-increasing agent, wherein the viscosity-increasing agent comprises a water-soluble hydrophilic polymer;
(iii) a fluid-loss control agent; and
(iv) a cyclodextrin-based compound; and
(B) drilling in the zone,
wherein the water-based drilling fluid does not include a hydrophobically-modified hydrophilic polymer.
2. The method according to claim 1 , wherein the cyclodextrin-based compound does not interact with the viscosity-increasing agent to increase or decrease the viscosity of the water-based drilling fluid by more than 10 cP.
3. The method according to claim 1 , wherein the water-based drilling fluid has less than a sufficient concentration of a viscoelastic surfactant to increase the viscosity of the water-based drilling fluid by more than 10 cP.
4. The method according to claim 1 , wherein the water-based drilling fluid contains less than 0.01% by weight of the water of a viscoelastic surfactant.
5. The method according to claim 1 , wherein the continuous water phase comprises a source of water selected from the group consisting of freshwater, seawater, brine, or any combination thereof.
6. The method according to claim 1 , wherein the water-based drilling fluid additionally comprises a weighting agent.
7. The method according to claim 6 , wherein the weighting agent is in at least a sufficient concentration such that the continuous water phase has a density of at least 9 ppg.
8. The method according to claim 6 , wherein the weighting agent comprises a water-soluble inorganic salt.
9. The method according to claim 6 , wherein the weighting agent comprises barium sulfate.
10. The method according to claim 6 , wherein the weighting agent is a solid particulate selected from the group consisting of: hematite, calcium carbonate, and any combination thereof.
11. The method according to claim 6 , wherein the weighting agent is a solid particulate having a particle size distribution anywhere in the range of 400 US mesh to 100 US mesh.
12. The method according to claim 1 , wherein the water-based drilling fluid includes less than 10% of any combination of dissolved alkali metal halide salts by weight of the water.
13. The method according to claim 1 , wherein the viscosity-increasing agent comprises a cellulosic polymer, a polyacrylic polymer, or natural gum polymer.
14. The method according to claim 1 , wherein the fluid-loss control agent is selected from the group consisting of: bentonite particulate, an organic colloidal-sized solid particulate; a filter cake bridging material, a lost-circulation particulate, and any combination thereof; and wherein the fluid-loss control agent does not comprise a hydrophobically-modified hydrophilic polymer.
15. The method according to claim 1 , wherein the fluid-loss control agent is a particulate selected from the group consisting of bentonite, a biopolymer, cellulose polymer, modified cellulose, starch, modified starch, polyanionic cellulose, plant tannin, a polyphosphate, a lignitic material, a lignosulfonate, a synthetic polymer, calcium carbonate, asphalt, gilsonite, walnut shells, and mica; and wherein the fluid-loss control agent does not include a hydrophobically-modified hydrophilic polymer.
16. The method according to claim 1 , wherein the fluid-loss control agent is selected from the group consisting of polyanionic cellulose, modified starch, and any combination thereof in any proportion; and wherein the fluid-loss control agent does not include a hydrophobically-modified hydrophilic polymer.
17. The method according to claim 1 , wherein the fluid-loss control agent is in a concentration of at least 1 ppg of the continuous water phase.
18. The method according to claim 1 , wherein the cyclodextrin-based compound is a cyclodextrin.
19. The method according to claim 1 , additionally comprising the step of: forming the water-based fluid.
20. The method according to claim 1 , wherein the zone penetrates or is in a subterranean formation of shale.
21. The method according to claim 1 , wherein the cyclodextrin-based compound stabilizes a shale formation.
22. A method of drilling a zone of a well, the method comprising the steps of:
(A) introducing a water-based drilling fluid into the zone, the water-based drilling fluid comprising:
(i) a continuous water phase;
(ii) a viscosity-increasing agent, wherein the viscosity-increasing agent comprises a water-soluble hydrophilic polymer;
(iii) a fluid-loss control agent; and
(iv) a cyclodextrin-based compound, wherein the cyclodextrin-based compound does not interact with the viscosity-increasing agent to increase or decrease the viscosity of the water-based drilling fluid by more than 10 cP; and
(B) drilling in the zone,
wherein the water-based drilling fluid does not contain a hydrophobically-modified hydrophilic polymer.