US 12,292,212 B2
Optimizing well placement to maximize exposed hydraulic fracture area in geothermal wells
Robert Barree, Lakewood, CO (US); Ronald Glen Dusterhoft, Houston, TX (US); and Neil Alan Stegent, Houston, TX (US)
Assigned to Halliburton Energy Services, Inc., Houston, TX (US)
Filed by Halliburton Energy Services, Inc., Houston, TX (US)
Filed on Jun. 15, 2023, as Appl. No. 18/210,211.
Prior Publication US 2024/0418412 A1, Dec. 19, 2024
Int. Cl. F24T 10/20 (2018.01); E21B 7/04 (2006.01); E21B 33/03 (2006.01); F03G 4/06 (2006.01); F24T 50/00 (2018.01); G06F 30/28 (2020.01); E21B 43/26 (2006.01); E21B 49/00 (2006.01)
CPC F24T 10/20 (2018.05) [E21B 7/04 (2013.01); E21B 33/03 (2013.01); F03G 4/06 (2021.08); F24T 50/00 (2018.05); G06F 30/28 (2020.01); E21B 43/26 (2013.01); E21B 49/00 (2013.01); F24T 2201/00 (2018.05)] 27 Claims
OG exemplary drawing
 
1. A system for producing geothermal energy from a subterranean formation, comprising:
an injection well comprising a curved wellbore extending into the subterranean formation from an injection wellhead at a surface location, wherein the curved wellbore comprises an injection area value greater than an injection area value of a horizontal wellbore;
a production well fluidically coupled to the injection well comprising a horizontal production wellbore penetrating the subterranean formation from a production wellhead at the surface location, and wherein the production well has a production area value less than the injection area value of the injection well;
an energy production system fluidically coupled to the injection wellhead and the production wellhead configured to generate electric power from an elevated temperature of a production fluid; and
wherein the elevated temperature and flowrate of the production fluid is a function of a pressure and a flowrate of an injection fluid.