High temperature temporary diverter and lost circulation material
A method can include introducing a particulate diverting agent into a first fracture within an underground reservoir formation. The particulate diverting agent can at least partially hydraulically isolate the first fracture. The particulate diverting agent can also be a temporary material which substantially degrades over an extended time. The underground reservoir formation can be stimulated with a stimulation fluid sufficient to expand a second fracture within the underground reservoir formation. The particulate diverting agent can then be allowed to substantially degrade.
1. A method of hydraulic stimulation in underground reservoir formations, comprising:
introducing a particulate diverting agent into a first fracture within an underground reservoir formation sufficient to at least partially hydraulically isolate the first fracture, the particulate diverting agent being a temporary material which substantially degrades over an extended time upon exposure to heat at a degradation temperature;
stimulating the underground reservoir formation with a stimulation fluid at a temperature below the degradation temperature sufficient to expand a second fracture within the underground reservoir formation; and
allowing the particulate diverting agent to substantially degrade by reducing flow of the stimulation fluid to allow native heat within the underground reservoir formation to heat the particulate diverting agent to the degradation temperature.
2. The method of claim 1 , wherein the particulate diverting agent is selected from the group consisting of polymer, glass, acid-base cement and combinations thereof.
3. The method of claim 2 , wherein the particulate diverting agent is a polyester selected from the group consisting of polyethylene teraphthalate (PET), polybutylene succinate (PBS), polycaprolactone (PCL), polypropylene fumarate (PPF), polyhydroxyalkanoates (PHA), and combinations thereof.
4. The method of claim 2 , wherein the particulate diverting agent is a thermoset polymer selected from the group consisting of thermoset phenol formaldehyde resin, polyether ether ketone (PEEK), and combinations thereof.
5. The method of claim 2 , wherein the particulate diverting agent is a polycarbonate, rayon, polyvinyl alcohol, polyglycolic acid, and combinations thereof.
6. The method of claim 5 , wherein the particulate diverting agent is a polycarbonate including at least one of polybisphenyl carbonate and polypropylene carbonate.
7. The method of claim 2 , wherein the particulate diverting agent is a polyaramid.
8. The method of claim 2 , wherein the particulate diverting agent is at least one of poly(isophthaloyl chloride/m-phenylenediamine) (NOMEX) and poly-paraphenylene teraphthalamide (KEVLAR).
9. The method of claim 2 , wherein the particulate diverting agent is calcium carbonate.
10. The method of claim 2 , wherein the particulate diverting agent is amorphous or crystalline silicon dioxide.
11. The method of claim 2 , wherein the particulate diverting agent is a glass selected from the group consisting of borosilicate glass, soda lime glass, flint glass, fiberglass, and combinations thereof.
12. The method of claim 2 , wherein the particulate diverting agent is a acid-base cement selected from the group consisting of magnesium oxy-acid cement, magnesium ammonium phosphate cement, magnesium potassium phosphate cement, magnesium oxyphosphate cement, calcium aluminate cement, and combinations thereof.
13. The method of claim 1 , wherein the particulate diverting agent is selected from the group consisting of calcium carbonate, amorphous silicon dioxide, crystalline silicon dioxide, alumina, aluminum hydroxide, aluminum oxyhydroxide (Boehmite), and combinations thereof.
14. The method of claim 1 , wherein the introducing and stimulating occur within a common subterranean well.
15. The method of claim 14 , wherein the common subterranean well does not include a well casing.
16. The method of claim 1 , wherein the underground reservoir formation is a geothermal reservoir.
17. The method of claim 1 , wherein the stimulating occurs sufficient to expand the second fracture under shear.
18. The method of claim 1 , wherein the stimulation fluid is circulated at a flow rate sufficient to cool the particulate diverting agent to a stability temperature where the particulate diverting agent is stable for at least 1 days.
19. The method of claim 1 , further comprising:
introducing additional particulate diverting agent into the second fracture to at least partially hydraulically isolate the second fracture prior to the step of allowing the particulate diverting agent within the first fracture to substantially degrade; and
stimulating the underground reservoir formation sufficient to produce or expand a third fracture within the underground reservoir formation.