Wellbore treatment fluids with no-heat liquid solder additives

1. A method comprising:

positioning a mixture downhole in a wellbore, the mixture comprising:

particles comprising a metal material in an undercooled state coated with a layer that is controllably activatable to release the metal material in a liquid state in the wellbore; and

a wellbore treatment material; and

activating the layer to release the metal material in the liquid state from the particles downhole in the wellbore, wherein the metal material in the liquid state flows and solidifies to form solid metal material; and

performing a wellbore treatment operation using the solid metal material by filling or plugging a void or crack in the wellbore or in the wellbore treatment material.

2. The method of claim 1 , wherein activating the layer comprises subjecting, at a downhole location, the layer to heat, ultrasonic energy, a magnetic field, an electric field, a compressive stress, a shear stress, or a chemical dissolution treatment to release the metal material in the liquid state into the wellbore.

3. The method of claim 1 , wherein the wellbore treatment material comprises or is cured to form a cured cement, an uncured cement, a cured polymeric material, an uncured polymeric material or polymer precursor, a cured resin, or an uncured resin.

4. The method of claim 1 , wherein the wellbore treatment material comprises uncured cement or resin, the method further comprising curing the uncured cement or resin to form cured cement or cured resin while the particles of the metal material in the undercooled state and coated with the layer are embedded in the wellbore treatment material, wherein the layer is activated upon being subjected to forces that create damage to the cured cement or cured resin, and wherein the wellbore treatment operation comprises the metal material flowing to a location of the damage to solidify and at least partly seal the damage.

5. The method of claim 4 , wherein the cement comprises casing cement and wherein the damage includes damage to a casing string, the wellbore treatment operation comprising filling damage to the casing string with solidified metal material to form a seal.

6. The method of claim 1 , wherein the wellbore treatment material comprises lost-circulation material, wherein the wellbore treatment operation comprises filling or plugging a loss zone in the wellbore using the mixture, and wherein activating the layer releases the metal material in the liquid state to generate a metal-bonded filter cake comprising the lost-circulation material and the solid metal material for filling or plugging the loss zone.

7. The method of claim 6 , wherein activating the layer occurs by subjecting the layer to a pressure differential within the loss zone.

8. The method of claim 1 , wherein the wellbore treatment material is cement for cementing a casing string, the method further comprising detecting a position of the metal material in the wellbore for creating a cement bond log.

9. The method of claim 8 , wherein the wellbore treatment material comprises lead cement for cementing a portion of the casing string, the method further comprising detecting a position of the metal material for locating a top of cement.

10. The method of claim 1 , wherein the layer comprises one or more of a metal oxide layer, an organic adlayer, an inorganic adlayer, or an organic functional group, wherein the particles are dispersed in, suspended in, or supported by the wellbore treatment material, and wherein the metal material comprises Field's metal, Wood's metal, Cerrosafe, Rose's metal, or an alloy or a eutectic alloy of one or more of bismuth, lead, tin, indium, cadmium, thallium, gallium, zinc, copper, silver, gold, or antimony.

11. The method of claim 1 , wherein the metal material expands as it solidifies to at least partially fill the crack or the void.

12. The method of claim 1 , wherein the metal material has a larger specific gravity than the wellbore treatment material.

13. The method of claim 1 , wherein the mixture has specific gravity of from 3 to 12.

14. The method of claim 1 , wherein the metal material has a larger tensile strength than the wellbore treatment material.

15. The method of claim 1 , wherein the particles comprise 5% to 95% by weight of the mixture.

16. The method of claim 1 , wherein the wellbore treatment material is a curable material.

17. The method of claim 16 , wherein the curable material contracts upon curing, and wherein activating the layer occurs upon curing of the wellbore treatment material where contraction of the wellbore treatment material applies stress on the layer.

18. The method of claim 16 , wherein activating the layer occurs after curing the wellbore treatment material.

19. The method of claim 16 , further comprising curing the wellbore treatment material.