High thermal coefficient slurry compositions and methods therefor
A high-thermal conductivity slurry composition is contemplated that includes a slurry mixture comprising a high-thermal k material, water, and an optional dispersant. Preferably, the high thermal k material is in the form of a plurality of particles having a wide size distribution that spans across at least 2 log units and is present in an amount effective such that the slurry composition has, upon compaction or settling of the slurry mixture at a target location, a thermal conductivity of at least 3 W/m° K.
1. A non-cementitious high-thermal conductivity slurry composition, comprising:
a high-thermal k material and an optional dispersant, wherein the high thermal k material is in form of a plurality of particles having a wide size distribution;
wherein the wide size distribution spans across at least 2 log units;
wherein the high-thermal k material is present in an amount effective such that the slurry composition has, upon compaction or settling of a slurry mixture at a target location, a thermal conductivity of at least 3 W/m° K; and
wherein the slurry mixture is substantially free of curable materials.
2. The composition of claim 1 , wherein the slurry composition further comprises at least one functional agent selected from the group consisting of a plasticizer, a surfactant, an organic polymer, a silica filler, a NaCl or KCl or other inorganic salt, and a clay.
3. The composition of claim 1 , wherein the wide size distribution spans across at least 3 log units or is between 0.1 μm and 5.0 mm.
4. The composition of claim 1 , wherein the high-thermal k material is selected from the group consisting of graphite powder, flaked graphite, pyrolytic graphite, desulfurized petroleum coke, graphene, fly ash, copper powder, aluminum nitride, and silicon carbide.
5. The composition of claim 1 , wherein the high-thermal k material is present in the slurry mixture in an amount of at least 10 wt %.
6. The composition of claim 1 , wherein the high-thermal k material is present in an amount effective such that the slurry mixture has, upon compaction or settling at the target location, a thermal conductivity of at least 4 W/m° K.
7. The composition of claim 1 , wherein the slurry mixture has upon addition of water a sedimentation rate of the plurality of particles that allows pumping the slurry mixture to the target location without substantial settling of the particles before reaching the target location.
8. The composition of claim 7 having, upon addition of the water, a density of between 10 and 30 lb/gal and/or a water content of between 1 and 20 gal/100 lbs of high thermal k material.
9. A method of producing a pumpable slurry mixture, comprising:
combining the high-thermal conductivity slurry composition of claim 1 with a quantity of water; and
mixing the water with the high-thermal conductivity slurry composition to thereby form the pumpable slurry mixture;
wherein the quantity of water is sufficient to generate a slurry density of between 10 and 30 lb/gal.
10. The method of claim 9 , further comprising a step of feeding the pumpable slurry to a pump that pumps the slurry into a wellbore.
11. The method of claim 10 , wherein the step of pumping the slurry into the wellbore is performed at a rate that allows at least partial compaction or settling of the slurry mixture at the target location.
12. A method of installing a high-thermal conductivity mixture in a wellbore, comprising:
pumping a pumpable slurry comprising the non-cementitious high-thermal conductivity slurry composition of claim 1 to a target location having a target temperature of at least 200° C.;
wherein the pumpable slurry is routed into an annular space between the wellbore and a casing located in the wellbore, thereby displacing a fluid in the annular space;
removing the displaced fluid through a return space located within the casing; and
allowing the pumpable slurry to compact in at least a portion of the annular space to thereby form the high-thermal conductivity composition in the wellbore, wherein the high-thermal conductivity composition is in thermal exchange with at least a portion of the casing and at least a portion of a formation surrounding the wellbore;
wherein the pumpable slurry is pumped in place and after placement allowed at least partial compaction or settling of the slurry at the target location.
13. The method of claim 1 wherein the target location is at least 3,000 ft below ground and extends in a substantially vertical orientation.
14. The method of claim 12 , wherein the return space located within the casing is enclosed in a secondary conduit that is located within the casing, and wherein a second annular space is formed between the casing and the secondary conduit.
15. The method of claim 12 , wherein the step of removing the displaced fluid through the return space uses a secondary fluid that moves from the second annular space to the return space.
16. The method of claim 12 , wherein the formation includes a plurality of fissures that are at least partially filled with a high-thermal conductivity material, and wherein the high-thermal conductivity material in the fissures is in thermal exchange with the compacted high-thermal conductivity composition in the wellbore.
17. The method of claim 16 , wherein the high-thermal conductivity material in the fissures is selected from the group consisting of graphite powder, flaked graphite, pyrolytic graphite, desulfurized petroleum coke, graphene, fly ash, copper powder, aluminum nitride, and silicon carbide.
18. The method of claim 12 , further comprising a step of pumping water to the at least partially compacted or settled slurry at the target location after the slurry has compacted or settled to maintain or increase thermal conductivity of the compacted or settled slurry at the target location.
19. A method of reducing loss of thermal conductivity of a non-cementitious high-thermal conductivity composition in a wellbore, comprising:
providing in situ water to the non-cementitious high-thermal conductivity composition, wherein the non-cementitious high-thermal conductivity composition has compacted or settled at a target location and does not exhibit hardening or curing;
wherein the water is provided through an annular space between a casing of a closed loop circuit and a well wall or well casing; and
wherein the water is provided in an amount sufficient to reduce loss of thermal conductivity of the non-cementitious high-thermal conductivity composition relative to a time of placement of the non-cementitious high-thermal conductivity composition.
20. The method of claim 19 , wherein the non-cementitious high-thermal conductivity composition has a permeability for water that allows penetration of the water throughout at least 75% of the compacted or settled non-cementitious high-thermal conductivity composition.