US 12,078,772 B2
Gas saturation distribution monitoring in hydrocarbon reservoir
Yongchae Cho, Houston, TX (US); Yang Cao, College Station, TX (US); Yevgeniy Zagayevskiy, Houston, TX (US); Terry W. Wong, Spring, TX (US); and Yuribia Patricia Munoz, Pearland, TX (US)
Assigned to Landmark Graphics Corporation, Houston, TX (US)
Appl. No. 17/617,476
Filed by Landmark Graphics Corporation, Houston, TX (US)
PCT Filed Jul. 29, 2019, PCT No. PCT/US2019/043835
§ 371(c)(1), (2) Date Dec. 8, 2021,
PCT Pub. No. WO2021/021097, PCT Pub. Date Feb. 4, 2021.
Prior Publication US 2022/0236444 A1, Jul. 28, 2022
Int. Cl. E21B 47/00 (2012.01); E21B 43/16 (2006.01); E21B 49/08 (2006.01); G01V 7/06 (2006.01)
CPC G01V 7/06 (2013.01) [E21B 43/168 (2013.01); E21B 49/087 (2013.01); E21B 2200/20 (2020.05)] 19 Claims
OG exemplary drawing
 
1. A method comprising:
collecting, from a first set of gravity sensors, a first set of multicomponent borehole gravity data at a first time step along a first length of a first wellbore;
collecting, from a second set of gravity sensors, a second set of multicomponent borehole gravity data at the first time step along a second length of a second wellbore;
interpolating a third set of multicomponent borehole gravity data at the first time step in an area between the first wellbore and the second wellbore using the first set of multicomponent borehole gravity data and the second set of multicomponent borehole gravity data, wherein the area between the first wellbore and the second wellbore is at least partially out of a first range of the first set of gravity sensors and a second range of the second set of gravity sensors;
generating a three-dimensional fluid saturation model of a reservoir at the first time step, wherein the reservoir contains the first wellbore, the second wellbore, and the area between the first wellbore and the second wellbore, and wherein the three-dimensional fluid saturation model is generated using the first set, the second set, and the third set of multicomponent borehole gravity data;
determining, based on the three-dimensional fluid saturation model, a first fluid saturation in the reservoir;
determining a fluid saturation change in the reservoir between the first time step and a second time step by comparing the first fluid saturation in the reservoir with a second fluid saturation in the reservoir for the second time step; and
controlling wellbore production operations or wellbore injection operations at the first wellbore based on the fluid saturation change.