Electro-hydrofracturing using electrically conductive proppants and related methods
The present disclosure describes electro-hydrofracturing (E-HF) using electrically conductive proppants and methods for hydraulic fracturing using electrically conductive proppants.
1 . A system comprising:
two or more electrodes configured to apply an electrical potential between at least two well bores using electrohydraulic fracturing to heat at least a portion of a reservoir to a first temperature and to induce fracture propagation in a fracture network between the at least two well bores; and
one or more pumps, wherein at least one of the one or more pumps being configured to inject a hydraulic fracturing composition comprising a transport fluid and a conductive proppant into the reservoir,
wherein the two or more electrodes are configured to heat the hydraulic fracturing composition to a temperature between or equal to 500° C. and 1,000° C., wherein at least one of the one or more pumps is configured to inject a cooling fluid into the heated portion of the reservoir after the fracture propagation to thermally shock the reservoir to generate additional fracturing in the fracture network, wherein the cooling fluid is at a second temperature less than the first temperature when injected into the reservoir, wherein the reservoir is a geothermal reservoir, wherein the cooling fluid is heated following injection into the reservoir, and wherein at least one of the one or more pumps is configured to pump the heated cooling fluid from the geothermal reservoir after fracturing.
2 . The system of claim 1 , wherein the cooling fluid is water or brine.
3 . The system of claim 1 , wherein the one or more pumps are configured to flow the cooling fluid through the heated portion of the reservoir.
4 . The system of claim 1 , wherein the second temperature is a surface temperature.
5 . The system of claim 1 , wherein the second temperature is less than or equal to 20° C.
6 . The system of claim 1 , wherein the conductive proppant comprises petroleum coke.
7 . The system of claim 6 , wherein the conductive proppant comprises conductive carbon particles.
8 . The system of claim 6 , wherein the conductive proppant comprises ceramic particles.
9 . The system of claim 6 , wherein the conductive proppant comprises ceramic particles comprising a metallic coating.
10 . The system of claim 1 , wherein the two or more electrodes are configured to apply a plurality of electrical pulses between the at least two well bores.
11 . The system of claim 1 , wherein the electrical potential has a voltage greater than or equal to 1 kV and less than or equal to 100 kV.
12 . The system of claim 1 , wherein the electrical potential has a power greater than or equal to 1 MW and less than or equal to 1,000 MW.
13 . The system of claim 1 , wherein the two or more electrodes are configured to heat the hydraulic fracturing composition to a temperature between or equal to 750° C. and 900° C.
14 . The system of claim 1 , wherein the one or more pumps are configured to pump the heated fluid from the reservoir to a geothermal power plant.
15 . A method for fracturing a reservoir, the method comprising:
injecting a hydraulic fracturing composition comprising a transport fluid and a conductive proppant into the reservoir;
applying an electrical potential between at least two well bores using electrohydraulic fracturing to heat the reservoir to a first temperature and induce fracture propagation in a fracture network between the at least two well bores, wherein applying the electrical potential heats the hydraulic fracturing composition to a temperature between or equal to 500° C. and 1,000° C.;
injecting a cooling fluid into the reservoir after the fracture propagation to thermally shock the reservoir to generate additional fracturing in the fracture network, wherein the cooling fluid is at a second temperature less than the first temperature when injected into the reservoir, wherein the reservoir is a geothermal reservoir, and wherein the cooling fluid is heated following injection into the reservoir; and
pumping the heated cooling fluid from the geothermal reservoir after fracturing.
16 . The method of claim 15 , wherein the cooling fluid is water or brine.
17 . The method of claim 15 , further comprising flowing the cooling fluid through a heated region of the reservoir.
18 . The method of claim 15 , wherein the second temperature is a surface temperature.
19 . The method of claim 18 , wherein the second temperature is less than or equal to 20° C.
20 . The method of claim 15 , further comprising determining an electrical resistivity of portions of the reservoir filled with the hydraulic fracturing composition and determining an electrical resistivity of at least some portions of the reservoir not filled with the hydraulic fracturing composition.
21 . The method of claim 15 , wherein applying the electrical potential between the at least two well bores includes applying a plurality of electrical pulses.
22 . The method of claim 15 , wherein applying the electrical potential heats the hydraulic fracturing composition to a temperature between or equal to 750° C. and 900° C.
23 . The method of claim 15 , wherein pumping the heated fluid from the geothermal reservoir includes pumping the heated fluid from the reservoir to a geothermal power plant.
24 . A method for fracturing a reservoir, the method comprising:
injecting a hydraulic fracturing composition comprising a transport fluid and a conductive proppant into the reservoir;
applying an electrical potential between at least two well bores using electrohydraulic fracturing to heat the reservoir to a first temperature and induce fracture propagation in a fracture network between the at least two well bores, wherein applying the electrical potential heats the hydraulic fracturing composition to a temperature between or equal to 500° C. and 1,000° C.;
injecting a cooling fluid into the reservoir after the fracture propagation to thermally shock the reservoir to generate additional fracturing in the fracture network, wherein the cooling fluid is at a second temperature less than the first temperature when injected into the reservoir, wherein the reservoir is a mineral mining reservoir, and wherein the cooling fluid is heated following injection into the reservoir; and
pumping the heated cooling fluid from the mineral mining reservoir after fracturing.
25 . The method of claim 24 , further comprising flowing the cooling fluid through a heated region of the reservoir.
26 . The method of claim 24 , further comprising determining an electrical resistivity of portions of the reservoir filled with the hydraulic fracturing composition and determining an electrical resistivity of at least some portions of the reservoir not filled with the hydraulic fracturing composition.
27 . The method of claim 24 , wherein the second temperature is less than or equal to 20° C.