US 12,312,943 B2
Downhole pressure sensing for fluid identification
John Paul Bir Singh, Kingwood, TX (US); Mikko Jaaskelainen, Houston, TX (US); Krishna Babu Yerubandi, Houston, TX (US); and John L. Maida, Houston, TX (US)
Assigned to HALLIBURTON ENERGY SERVICES, INC., Houston, TX (US)
Filed by HALLIBURTON ENERGY SERVICES, INC., Houston, TX (US)
Filed on Nov. 17, 2020, as Appl. No. 16/950,556.
Claims priority of provisional application 62/969,019, filed on Feb. 1, 2020.
Claims priority of provisional application 62/969,022, filed on Feb. 1, 2020.
Claims priority of provisional application 62/968,985, filed on Jan. 31, 2020.
Prior Publication US 2021/0238983 A1, Aug. 5, 2021
Int. Cl. E21B 47/07 (2012.01); E21B 47/135 (2012.01); E21B 47/18 (2012.01); G01D 5/26 (2006.01); G01H 9/00 (2006.01); G01K 11/32 (2021.01); G01L 11/02 (2006.01)
CPC E21B 47/07 (2020.05) [E21B 47/135 (2020.05); E21B 47/18 (2013.01); G01D 5/268 (2013.01); G01H 9/004 (2013.01); G01K 11/32 (2013.01); G01L 11/025 (2013.01)] 17 Claims
OG exemplary drawing
 
14. A non-transitory computer-readable storage medium comprising:
instructions stored on the non-transitory computer-readable storage medium, the instructions, when executed by one or more processors, cause the one or more processors to:
receive one or more optical signals from a distributed acoustic sensing enabled fiber optic line positioned in a wellbore during a cementing process;
determine an acoustic noise attenuation received from the one or more optical signals from the distributed acoustic sensing enabled fiber optic line;
determine a slope and a variation of the acoustic noise attenuation;
receive pH data of fluid proximate to the wellbore from one or more sensors;
determine types of fluid proximate to the wellbore based on the slope and variation of the acoustic noise attenuation and the pH data;
determine a fluid density at a specific depth of the types of fluid at the position;
determine pressure gradients of the types of fluid based on the one or more optical signals received from the distributed acoustic sensing enabled fiber optic line;
compile flow profiles for the types of fluid proximate to the wellbore based on the determination of the types of fluid and the determination of the pressure gradients of the types of fluid in real time; and
after compiling the flow profiles, adjust the cementing process based on the flow profiles by a manual action or automatic action,
wherein adjusting the cementing process includes adjusting a volume of a fluid delivered to the wellbore based on a loss of fluid determined by the flow profiles and stopping the cementing process when cement is properly positioned,
wherein the pressure gradients are operable to determine one or more loss zones.