Inhibitive divalent wellbore fluids, methods of providing said fluids, and uses thereof

11746,275

16/882681

May 25, 2020

A wellbore fluid includes an aqueous fluid, a viscosifer, a stabilizer agent, and a lubricant. The aqueous fluid is an inhibitive divalent fluid. A method of preparing the divalent wellbore fluid includes are provided or formulated, methods produce the divalent wellbore fluids, and methods inject or circulate the inhibitive divalent wellbore fluids into a wellbore or borehole provided in a formation and/or into a reservoir of the formation.

M-I L.L.C. (Houston, TX, US)

SCHLUMBERGER TECHNOLOGY CORPORATION (Sugar Land, TX, US)

1. A wellbore fluid comprising: an aqueous fluid; a primary viscosifier comprising a starch derivative; a stabilizer agent; and a lubricant, wherein the aqueous fluid is an inhibitive divalent fluid; further comprising a secondary viscosifier present in the wellbore fluid at a concentration from about 0.5 to about 7 kg/m 3 ; wherein the stabilizer agent is a blend of polymeric alkaline materials wherein the wellbore fluid is a biopolymer-free fluid; and wherein the secondary viscosifier comprises a magnesium compound.

2. The wellbore fluid of claim 1 , wherein the aqueous fluid comprises a salt.

3. The wellbore fluid of claim 2 , wherein the salt is one selected from the group consisting of alkali metal chlorides, hydroxides, carboxylates, sodium, calcium, sulfur, aluminum, magnesium, potassium, strontium, silicon, lithium, and phosphorus salts of chlorides, bromides, carbonates, iodides, chlorates, bromates, formates, nitrates, oxides, and fluorides.

4. The wellbore fluid of claim 1 , wherein the aqueous fluid is a divalent brine base fluid.

5. The wellbore fluid of claim 4 , wherein the divalent brine base fluid has a density from about 1.0 to 1.5 g/cm3.

6. The wellbore fluid of claim 4 , wherein the divalent brine base fluid has a density up to about 3.0 g/cm3.

7. The wellbore fluid of claim 4 , wherein the divalent brine base fluid is a produced brine base fluid.

8. The wellbore fluid of claim 7 , wherein the produced brine base fluid comprises at least one heavy metal selected from the group consisting of As, Cd, Cr, Cu, Mn, Mo, Ni, Pb, Se, V, and Zn.

9. The wellbore fluid of claim 1 , wherein the primary viscosifier has a concentration from about 20 to about 40 kg/m3.

10. The wellbore fluid of claim 1 , wherein the lubricant is present in the wellbore fluid at a concentration to no more than 5%.

11. The wellbore fluid of claim 1 , wherein the wellbore fluid is selected from the group consisting of a drilling fluid, a cementing fluid, a completion fluid, a packing fluid, a work-over (repairing) fluid, a stimulation fluid, a well killing fluid, a spacer fluid, and a drill-in fluid.

12. A method of preparing a wellbore fluid, the method comprising: providing the wellbore fluid of claim 1 by mixing the aqueous fluid with the primary viscosifier, the secondary viscosifier, the stabilizer agent, and the lubricant to form the wellbore fluid, wherein the aqueous fluid comprises: the inhibitive divalent fluid; and a salt; and pumping the wellbore fluid into a wellbore.

13. The method of claim 12 , further comprising: retrieving the wellbore fluid from the wellbore; and filtering the wellbore fluid for a subsequent use.

14. The method of claim 12 , further comprising: formulating at least one cloud point polyglycol based shale stabilizer.

15. The wellbore fluid of claim 1 , wherein the primary viscosifier is a branched-chain starch derivative.

16. The wellbore fluid of claim 1 , wherein the lubricant is an alcohol or comprises at least one alkyl or at least one aryl in the form of an ester or ether.

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