Granted Patent B2

US 12,435,623 · App. 18/597,332 · Granted Oct 7, 2025

Inventors: Ayrat Gizzatov (Winchester, MA); Shitong Sherry Zhu (Waban, MA); Amy J. Cairns (Houston, TX); Rajesh Kumar Saini (Cypress, TX); Mohammed Sayed (Katy, TX); Wei Wang (Quincy, MA)

Assignee: SAUDI ARABIAN OIL COMPANY

E21B47/11C09K8/665C09K8/88E21B43/267

Abstract

Claims (28)

1. A method for monitoring gas production in a subterranean formation comprising:

introducing a polymer composite particle having a degradable portion and a non-degradable portion into a stimulation fluid,

wherein the non-degradable portion comprises a tracer,

wherein the degradable portion comprises a polymer that has hydrolysable bonds in the backbone,

wherein the polymer composite particle is a block copolymer wherein one block of the block copolymer is the degradable portion and one block of the block copolymer is the non-degradable portion, and

wherein the block copolymer is selected from the group consisting of thermoplastic copolyesters (TPC), thermoplastic polyurethane elastomers (TPU), and thermoplastic polyamides (TPA);

injecting the stimulation fluid comprising the polymer composite particle into the subterranean formation to a treatment stage of a treatment zone comprising at least one opening, wherein the polymer composite particle flows into and remains inside the at least one opening;

maintaining the polymer composite particle inside the at least one opening for an amount of time during which the polymer composite particle is exposed to moisture at a downhole temperature, wherein the moisture degrades the degradable portion of the polymer composite particle, thereby releasing the non-degradable portion comprising the tracer;

recovering produced gas from the subterranean formation, wherein the produced gas comprises a gaseous phase from the treatment stage of the treatment zone of the subterranean formation and the non-degradable portion comprising the tracer;

determining a presence of the non-degradable portion comprising the tracer in the produced gas; and

correlating the presence of the non-degradable portion comprising the tracer to the treatment stage of the treatment zone of the subterranean formation.

2. The method of claim 1 , further comprising:

injecting a second stimulation fluid comprising a second polymer composite particle having a degradable portion and a non-degradable portion comprising a second tracer into the subterranean formation to a second treatment stage of the treatment zone comprising at least one opening, wherein the second polymer composite particle flows into and remains inside the at least one opening;

maintaining the second polymer composite particle inside the at least one opening of the second treatment stage for an amount of time during which the second polymer composite particle is exposed to moisture at a downhole temperature, wherein the moisture degrades the degradable portion of the second polymer composite particle, thereby releasing the non-degradable portion comprising the second tracer;

detecting a presence of the non-degradable portion comprising the second tracer in the produced gas; and

correlating the presence of the non-degradable portion comprising the second tracer to the second treatment stage of the treatment zone.

3. The method of claim 1 , wherein the tracer is selected from the group consisting of tetrachloroisoindolinone orange, perylene red, quinacridone red, phthalocyanine blue, phthalocyanine green, disazo diarylide yellows, and combinations thereof.

4. The method of claim 1 , wherein the tracer is selected from the group consisting of ZnO, Fe 2 O 3 , Co 2 O 3 , Ni 2 O 3 , Cr 2 O 3 , CuO, MnO x , ZrO 2 , TiO 2 , ZnS, Ce 2 S 3 , and combinations thereof.

5. The method of claim 1 , wherein the polymer composite particle has an average particle size ranging from 10 microns to 10 millimeters.

6. The method of claim 1 , wherein the non-degradable portion of the polymer composite particle has an average particle size ranging from 100 nm to 300 microns.

7. The method of claim 1 , wherein the stimulation fluid is selected from the group consisting of an acidizing fluid, an organic acid, a fracturing fluid, a hydraulic fracturing fluid, an emulsified acid, a viscoelastic surfactant, a foamed fluid, a linear gel, a crosslinked gel, and combinations thereof.

8. The method of claim 1 , wherein the opening is a fracture, a wormhole, or a pore.

9. The method of claim 1 , wherein the amount of time is from 1 week to 12 weeks.

10. The method of claim 1 , wherein the subterranean formation comprises up to 80 treatment stages and wherein the method further comprises:

injecting a stimulation fluid comprising a distinct polymer composite particle having a degradable portion and a non-degradable portion comprising a distinct tracer into the subterranean formation at each treatment stage, such that up to 80 distinct polymer composite particles are injected into the subterranean formation, wherein each treatment stage comprises at least one opening and wherein each distinct polymer composite particle flows into and remains inside the at least one opening;

maintaining each of the up to 80 distinct polymer composite particles inside the at least one opening of each treatment stage for an amount of time during which each distinct polymer composite particle is exposed to moisture at a downhole temperature, wherein the moisture degrades the degradable portion of each distinct polymer composite particles, thereby releasing the non-degradable portion comprising the distinct tracer, such that up to 80 non-degradable portions, each comprising a distinct tracer are released at the same or different times;

detecting a presence of the distinct tracer of each of the up to 80 non-degradable portions in the produced gas; and

correlating the presence of the distinct tracer of each of the up to 80 non-degradable portions to one of the up to 80 treatment stages of the subterranean formation.

Continuity (2)

References Cited (48)