Methods for in-depth fluid diversion and stage by stage fluid diversion systems
A method for in-depth fluid diversion includes a first step and one or more second steps. The first step includes simultaneously introducing a preformed particle gel (PPG) material and one or more shrinking agents to a first position in a high-permeability zone via an injection well, and introducing water into the high-permeability zone via the injection well, thereby contacting the water with the PPG material to form water-swelled PPG particles within fractures of the high-permeability zone at the first position. The water-swelled PPG particles in the high-permeability zone can pack the fractures, thereby generating a fluid diversion to control the water flow to an adjacent low-permeability zone. A stage-by-stage fluid diversion system is also disclosed.
1 . A method for in-depth fluid diversion in a heterogenous reservoir, wherein the method comprising:
a first step comprising:
simultaneously introducing a preformed particle gel (PPG) material and a shrinking agent comprising a salinity water having a salinity of from 50,000 (parts per million) ppm to 360,000 ppm to a first position in a high-permeability zone comprising fractures that can be packed by the PPG material having a particle size of from 0.05 millimeters (mm) to 10 mm via an injection well;
terminating the introduction of the PPG material and the shrinking agent; and
flowing water having a salinity of from 50 ppm to 5,000 ppm into the high-permeability zone via the injection well, thereby contacting the water with the PPG material to form water-swelled PPG particles within the fractures of the high-permeability zone at the first position, wherein the water-swelled PPG particles in the high-permeability zone can pack the fractures, thereby generating a fluid diversion to control the water flow to an adjacent low-permeability zone, wherein the low-permeability zone is substantially free of fractures capable of being packed by the PPG material having the particle size of from 0.05 mm to 10 mm;
one or more second steps comprising:
terminating the introduction of the water having the salinity of from 50 ppm to 5,000 ppm;
reintroducing the shrinking agent comprising the salinity water having the salinity of from 50,000 ppm to 360,000 ppm via the injection well to the first position, thereby contacting the shrinking agent with the water-swelled PPG particles within the fractures to convert the water-swelled PPG particles to shrunken PPG particles, wherein the shrunken PPG particles are released from the fractures, thereby flowing to a second position of the high-permeability zone;
terminating the introduction of the shrinking agent comprising the salinity water; and
reintroducing the water having the salinity of from 50 ppm to 5,000 ppm into the high-permeability zone, thereby contacting the water with the shrunken PPG particles to convert the shrunken PPG particles to the water-swelled PPG particles within the fractures of the high-permeability zone at the second position, thereby regenerating the fluid diversion to control the water flow to the adjacent low-permeability zone.
2 . The method of claim 1 , wherein the PPG material is prepared from a composition comprising one or more monomers, one or more crosslinkers, and one or more fillers.
3 . The method of claim 2 , wherein the one or more monomers are selected from the group consisting of acrylamide (AM), acrylic acid (AA), and 2-acrylamido-2-methylpropane sulfonic acid (AMPS).
4 . The method of claim 2 , wherein the one or more monomers comprise acrylamide selected form the group consisting of methacrylamide, N, N-dimethyl (meth)acrylamide, 2-acrylamidoglycolic acid, N-hydroxypropylacrylamide, N-hydroxyethyl acrylamide, N-(tris(hydroxymethyl)methyl)-acrylamide, N-2-aminoethyl (meth)acrylamide hydrochloride, N-3-aminopropyl (meth)acrylamide hydrochloride, and combinations thereof.
5 . The method of claim 2 , wherein the one or more crosslinkers are selected from the group consisting of N,N-methylenebisacrylamide (MBA), diallyldimethylammonium chloride (DADMAC), and poly(ethylene glycol)diacrylate (PEGDA).
6 . The method of claim 2 , wherein the one or more fillers are selected from the group consisting of clay, calcium carbonate, and silica.
7 . The method of claim 1 , wherein the PPG material has a particle size of from 1 mm to 5 mm.
8 . The method of claim 1 , wherein the PPG material has a storage modulus of from 100 pascals (Pa) to 100,000 Pa.
9 . The method of claim 1 , wherein the shrinking agent further comprises an alcohol.
10 . The method of claim 9 , wherein the salinity water has a salinity of 213,734 ppm.
11 . The method of claim 9 , wherein the alcohol is selected from the group consisting of methanol, ethanol, isopropanol, 1-propanol, ethylene glycol, 1,2-propanediol, 1,3-propanediol, diethylene glycol, and dipropylene glycol.
12 . The method of claim 1 , wherein the injection well is selected from the group consisting of a vertical wellbore, a deviated wellbore, a multilateral wellbore, and a horizontal wellbore.
13 . The method of claim 12 , wherein the injection well is a vertical wellbore.
14 . The method of claim 1 , wherein the temperature of the heterogenous reservoir is from 60° C. to 150° C.
15 . The method of claim 1 , wherein a pressure at the first position of the high-permeability zone packed with the water-swelled PPG particles is 1 to 5 times higher compared to a pressure measured at the first position after converting the water-swelled PPG particles to shrunken PPG particles.
16 . The method of claim 1 , wherein the second position is at a further distance than the first position relative to the injection well.