US 12,228,014 B2
Volumetric treatment fluid distribution to remove formation damage
Mohammad Aljishi, Alqatif (SA); Fuad Alsultan, Alahsa (SA); and Keshabananda Baruah, Abqaiq (SA)
Assigned to SAUDI ARABIAN OIL COMPANY, Dhahran (SA)
Filed by SAUDI ARABIAN OIL COMPANY, Dhahran (SA)
Filed on Feb. 26, 2021, as Appl. No. 17/186,608.
Prior Publication US 2022/0275707 A1, Sep. 1, 2022
Int. Cl. E21B 37/00 (2006.01); E21B 41/00 (2006.01); E21B 47/04 (2012.01); E21B 47/12 (2012.01); E21B 49/00 (2006.01); E21B 49/08 (2006.01)
CPC E21B 37/00 (2013.01) [E21B 41/0078 (2013.01); E21B 47/04 (2013.01); E21B 47/12 (2013.01); E21B 49/005 (2013.01); E21B 49/087 (2013.01); E21B 2200/20 (2020.05)] 20 Claims
OG exemplary drawing
 
1. A method for selective fluid treatment of formation areas to remove formation damage, the method comprising:
accessing log data associated with a well, the log data including at least one of permeability values or porosity values associated with a plurality of formation areas;
identifying, based on the log data, a shallow resistivity value, a medium resistivity value, and a deep resistivity value;
identifying, using a hardware processor, a formation area of the plurality of formation areas as a treatment candidate area based on at least one of a permeability value associated with the formation area exceeding a permeability threshold value or a porosity value associated with the formation area exceeding a porosity threshold value;
determining, based on utilizing a first ratio between the shallow resistivity value and the deep resistivity value and a second ratio between the medium resistivity value and the deep resistivity value as inputs to a resistivity tornado chart, an initial depth of invasion by drilling mud into the formation area;
obtaining a time-dependent synthetic model of a reservoir comprising:
a fluid flow equation, comprising a time derivative of a water density in the formation area, the water density based on a water saturation and a water salinity;
a formation resistivity equation based on the water salinity; and
Archie's equation based on the water saturation and the formation resistivity;
determining a current depth of invasion by drilling mud into the formation area using the hardware processor, the time-dependent synthetic model of a reservoir, and an initial water saturation for the fluid flow equation based on the initial depth of invasion;
determine a volume of drilling mud buildup in the formation area based on the current depth of invasion; and
determining, using the hardware processor, a treatment fluid volume value that identifies a volume of treatment fluid for application to the formation area to remove the formation damage from the formation area during a formation damage removal process, the determining of the treatment fluid volume value being based on the volume of drilling mud buildup in the formation area.