Chemical compositions for geothermal well stimulation
A method, apparatus, system, and compositions for introducing diversion agents into a subterranean formation traversed by a wellbore with a heat transfer surface, including forming a first fluid comprising a diversion agent, introducing the first fluid into a region of the formation wherein the heat transfer surface is higher than if no agent were present, and introducing a second fluid for collecting heat from the formation. A method, apparatus, system, and compositions for introducing diversion agents into a subterranean formation traversed by a wellbore with a heat transfer surface, including forming a first fluid comprising a diversion agent, introducing the first fluid into a region of the formation wherein the formation is at least 350° F. and wherein the agent maintains its mechanical integrity at least 2 hours, and introducing a second fluid to the formation.
1 . A method, comprising:
performing a fracture treatment to form a fracture off a geothermal wellbore traversing a subterranean formation;
introducing a first fluid comprising a diversion agent into the fracture;
placing the diversion agent proximate a region of the fracture that is farthest from the geothermal wellbore, wherein a heat transfer surface area of the fracture is larger than if no diversion agent were present;
introducing a second fluid for collecting heat from the subterranean formation; and
producing hot water, steam, or a combination thereof via heat transfer between the second fluid and the subterranean formation;
wherein the first fluid is introduced periodically on a predetermined schedule, and the second fluid is introduced continuously.
2 . The method of claim 1 , wherein a temperature of the formation is 350° F. or hotter.
3 . The method of claim 1 , wherein the diversion agent comprises polyethylene terephthalate.
4 . The method of claim 3 , wherein the diversion agent is a polymer blend and further comprises polycaprolactone.
5 . The method of claim 3 , wherein the diversion agent is a polymer blend and further comprises polybutylene terephthalate.
6 . The method of claim 3 , wherein the diversion agent is a polymer blend and further comprises nylon.
7 . The method of claim 1 , wherein the diversion agent is present in the first fluid at a concentration between 30 and 60 weight percent.
8 . The method of claim 1 , wherein the diversion agent is present in the first fluid at a concentration between 10 and 90 weight percent.
9 . The method of claim 1 , wherein the diversion agent comprises an additive, wherein the additive is present in the diversion agent at a concentration between 10 and 50 weight percent.
10 . The method of claim 9 , wherein the additive comprises glass.
11 . The method of claim 1 , wherein the diversion agent comprises an additive, wherein the additive is present in the diversion agent at a concentration between 1 and 20 weight percent.
12 . The method of claim 11 , wherein the additive comprises a reinforcing additive.
13 . The method of claim 1 , wherein the diversion agent maintains its mechanical integrity for at least two hours, and wherein, during the at least two hours, the method further comprises hydraulic fracturing, fluid stimulation, or a combination thereof.
14 . The method of claim 1 , wherein:
the diversion agent is a polymer blend comprising polyethylene terephthalate and one of:
polycaprolactone, wherein the diversion agent is present in the first fluid at a concentration between 30 and 60 weight percent when the polymer blend comprises polyethylene terephthalate and polycaprolactone;
polybutylene terephthalate, wherein the diversion agent is present in the first fluid at a concentration between 30 and 60 weight percent when the polymer blend comprises polyethylene terephthalate and polybutylene terephthalate; or
nylon, wherein the diversion agent is present in the first fluid at a concentration between 10 and 90 weight percent when the polymer blend comprises polyethylene terephthalate and nylon;
the polyethylene terephthalate is reinforced with glass fiber present in the polyethylene terephthalate at a concentration of 30 weight percent;
the predetermined schedule is based on a degradation rate of the diversion agent and a reheating rate of the subterranean formation; and
the degradation rate and the reheating rate are determined based on at least one of:
modeled heat transfer and temperature behavior in the geothermal wellbore and the fracture;
temperature measurements obtained from the geothermal wellbore via one or more downhole sensors; or
monitored water heat content in the geothermal wellbore.
15 . A method, comprising:
performing a fracture treatment to form a fracture off a geothermal wellbore traversing a subterranean formation;
introducing a first fluid comprising a diversion agent into the fracture, wherein a temperature of the subterranean formation is at least 350° F., and wherein the diversion agent maintains its mechanical integrity for at least two hours;
placing the diversion agent proximate a region of the fracture that is farthest from the geothermal wellbore;
introducing a second fluid to the subterranean formation; and
producing hot water, steam, or a combination thereof via heat transfer between the second fluid and the subterranean formation;
wherein the first fluid is introduced periodically on a predetermined schedule, and the second fluid is introduced continuously.
16 . The method of claim 15 , wherein the diversion agent comprises polyethylene terephthalate.
17 . The method of claim 15 , wherein the diversion agent is present in the first fluid at a concentration between 10 and 90 weight percent.
18 . The method of claim 15 , wherein the diversion agent comprises an additive, wherein the additive is present in the diversion agent at a concentration between 10 and 50 weight percent.
19 . The method of claim 18 , wherein the additive comprises glass.
20 . The method of claim 15 , wherein the diversion agent comprises an additive, wherein the additive is present in the diversion agent at a concentration between 1 and 20 weight percent.