METHOD OF MONITORING FLUID FLOW FROM A RESERVOIR USING WELL TREATMENT AGENTS

• US 20170350236A1
• Filed: 06/02/2016
• Published: 12/07/2017
• Est. Priority Date: 06/02/2016
• Status: Active Grant

• Current Assignee: Baker Hughes Holdings LLC (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Shen, Dong, Szymczak, Stephen J., Steiner, William H., Galvan, Dora V.
• Granted Patent: US 10,641,083 B2
• Time in Patent Office: Days
• CPC Class Codes: C09K 8/03 Specific additives for general use in well-drilling compositions
• CPC Class Codes: C09K 8/524 organic depositions, e.g. paraffins or asphaltenes
• CPC Class Codes: C09K 8/528 inorganic depositions, e.g. sulfates or carbonates
• CPC Class Codes: C09K 8/536 characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: E21B 43/14 Obtaining from a multiple-zone well
• CPC Class Codes: E21B 43/25 Methods for stimulating production by vibrating earth formations E21B43/003
• CPC Class Codes: E21B 47/11 using tracers; using radioactivity

Abstract

A method of treating a multi-zoned subterranean formation with composites having well treatment agents is disclosed. The well treatment agent treated in each zone is distinguishable. At least a portion of the well treatment agent is released from one of the composites into the well or formation. The formation of undesirable contaminants may be inhibited or prevented in the well or in the formation by the release of the well treatment agent from one or more of the composites. The well treatment agent also serves as a tracer. When fluid transported from the formation or well is collected, the source of the transported fluid may be determined by comparing a chemical or physical parameter of the well treatment agent with a working set of known taggants.

Claims

1. A method of determining the source of a produced fluid from a multiple zone subterranean formation penetrated by a well comprising:

(a) introducing a first well treatment fluid in a first zone and a second well treatment fluid in a second zone of the subterranean formation, wherein the first well treatment fluid and the second well treatment fluid contain a composite comprising a well treatment agent and wherein the well treatment agent of the composite of the first well treatment fluid and the well treatment agent of the composite of the second well treatment fluid are different and distinguishable by physical or chemical analysis;

(b) releasing the well treatment agent from the composite of the first treatment fluid and/or the composite of the second treatment fluid;

(c) inhibiting and/or preventing the deposition of contaminants within the well and/or subterranean formation by the released well treatment agent of step (b);

(d) transporting produced fluid from the well and/or subterranean formation, the transported produced fluid containing at least a portion of the released well treatment agent of step (b);

(e) collecting at least a portion of the transported produced fluid;

(f) detecting the well treatment agent of the first treatment fluid and/or second treatment fluid in the collected fluid by physical or chemical analysis; and

(g) determining the source of the collected fluid from the detected well treatment agent.

2. The method of claim 1, wherein the well treatment agent of the composite of the first well treatment fluid and/or the second well treatment fluid contains a taggant and further wherein the well treatment agent in the collected fluid is detected from the taggant.

3. The method of claim 2, wherein the well treatment agent of the first well treatment fluid and the well treatment agent of the second well treatment fluid have a taggant and further wherein the taggant on the well treatment agent of the first well treatment fluid and the taggant on the well treatment agent of the second well treatment fluid are different.

4. The method of claim 3, wherein the well treatment agent of the first well treatment fluid and the well treatment agent of the second well treatment fluid differ only by the taggant.

5. The method of claim 4, wherein the composite of the first well treatment fluid and the composite of the second well treatment fluid differ only by the taggant on the well treatment agents of the first well treatment fluid and the second well treatment fluid.

6. The method of claim 2, wherein the well treatment agent of the collected fluid is detected by comparing the well treatment agent in the collected fluid with a working set of known taggants.

7. The method of claim 2, wherein at least one of the following conditions prevail:

(a) the composite of the first well treatment fluid comprises the well treatment agent adsorbed onto a water-insoluble adsorbent and/or the composite of the second well treatment fluid comprises the well treatment agent adsorbed onto a water-insoluble adsorbent;

(b) the composite of the first well treatment fluid comprises the well treatment agent immobilized on a support and/or the composite of the second well treatment fluid comprises the well treatment agent immobilized on a support;

(c) the composite of the first well treatment fluid comprises the well treatment agent immobilized within a matrix and/or the composite of the second well treatment fluid comprises the well treatment agent immobilized within a matrix;

or

(d) the composite of the first well treatment fluid comprises the well treatment agent immobilized on or within a porous particulate and/or the composite of the second well treatment fluid comprises the second well treatment agent immobilized on or within a porous particulate.

8. The method of claim 7, wherein the well treatment agent of the first well treatment fluid and/or the well treatment agent of the second well treatment fluid is immobilized within a binder and further wherein the well treatment agent and the binder are compressed to form a shaped article.

9. The method of claim 2, wherein the transported produced fluid is flowback water and further wherein the zone of the subterranean formation from which the flowback water originates is determined by identifying the taggant of the well treatment agent in the flowback water by physical or chemical analysis.

10. The method of claim 2, wherein the transported produced fluid is produced water and further wherein the zone of the subterranean formation from which the produced water originates is determined by identifying the taggant of the well treatment agent in the produced water.

11. The method of claim 2, wherein the transported produced fluid is gas or oil produced from the subterranean formation and further wherein the zone of the subterranean formation from which the produced gas or oil originates is determined by identifying the taggant of the well treatment agent in the produced gas or oil.

12. The method of claim 2, wherein the well treatment agent of the first well treatment fluid and/or the second well treatment fluid is a scale inhibitor, paraffin inhibitor, corrosion inhibitor, salt inhibitor or any combination thereof.

13. The method of claim 2, wherein the well treatment agent of the first treatment fluid and/or second treatment fluid is detected by atomic absorption spectroscopy, infrared spectroscopy, ultraviolet spectroscopy, mass spectroscopy, chromatography, fluorescence spectroscopy, neutron activation analysis, electrochemical detection, radioactive analysis, x-ray analysis, PCR techniques combined with sequential analysis, electron capture detection and inductively-coupled plasma discharge.

14. The method of claim 2, wherein the taggant of the tagged well treatment agent of the first well treatment fluid and/or the taggant of the tagged well treatment agent of the second well treatment fluid is selected from the group consisting of dyes, gases, acids, ionizable compounds, non-radioactive metals, phosphorescent pigments, fluorescent pigments, photoluminescent pigments, oil dispersible pigments, isotopes;

genetically or biologically coded materials, microorganisms, minerals and Groups I to VIII metals.

15. The method of claim 2, wherein the taggant of the tagged well treatment agent of the first well treatment fluid and/or the taggant of the tagged well treatment agent of the second well treatment fluid is a chelate.

16. A method of determining the source of a fluid transported from a well penetrating a multi-zone subterranean formation comprising:

(a) introducing into two or more of the multiple zones a well treatment fluid containing a composite comprising a well treatment agent wherein the well treatment agent of the composite introduced to each of the two or more multiple zones is different;

(b) collecting at least a portion of fluid transported from the well during or after completion of a well treatment operation; and

(c) determining the zone of the subterranean formation from which the transported fluid originates by detecting the well treatment agent in the transport fluid by a physical or a chemical detection method.

17. The method of claim 16, wherein the well treatment agent of each of the composites introduced into the two or more zones has a distinguishable taggant.

18. The method of claim 17, wherein the zone from which the transported fluid originates is determined by detecting the taggant on the well treatment agent in the collected fluid.

19. The method of claim 16, wherein at least one of the following prevails:

(a) the composite introduced into at least one of the two or more multiple zones comprises the well treatment agent adsorbed onto a water-insoluble adsorbent;

(b) the composite introduced into at least one of the two or more multiple zones comprises the well treatment agent immobilized on a support;

(c) the composite introduced into at least one of the two or more multiple zones comprises the well treatment agent immobilized within a matrix;

or

(d) the composite introduced into at least one of the two or more multiple zones comprises the well treatment agent immobilized on or within a porous particulate.

20. The method of claim 17, wherein at least one of the following conditions prevail:

(a) the transported fluid is flowback water and the zone of the subterranean formation from which the flowback water originates is determined by comparing the taggant of the well treatment agent in the flowback water by a physical or a chemical detection method;

(b) the transported fluid is produced water and the zone of the subterranean formation from which the produced water originates is determined by comparing the taggant of the well treatment agent in the produced water by a physical or chemical detection method;

or

(c) the transported fluid is gas or oil produced from the subterranean formation and further wherein the zone of the subterranean formation from which the produced gas or oil originates is determined by a physical or chemical detection method.

21. A method of inhibiting or preventing the deposition of contaminants within a subterranean formation or a well penetrating the subterranean formation and determining the source of a fluid transported from a subterranean formation, wherein the subterranean formation has multiple zones penetrated by the well, the method comprising:

(a) introducing into two or more of the multiple zones a composite comprising a well treatment agent wherein the well treatment agent of the composite introduced into each of the two or more multiple zones is different;

(b) inhibiting or prevent the deposition of contaminants in the subterranean formation and/or well by disassociating the well treatment agent from the composite under in-situ conditions;

(c) collecting at least a portion of fluid transported from the well during or after completion of a well treatment operation, wherein the collected fluid contains the disassociated well treatment agent; and

(d) determining the zone of the subterranean formation from which the transported fluid originated by detecting the well treatment agent in the transported fluid by a chemical or physical method.

22. The method of claim 21, wherein the well treatment agent of the composite of the first well treatment fluid and/or the second well treatment fluid has a distinguishable taggant.

23. The method of claim 22, wherein at least one of the following prevails:

(a) the well treatment agent of the composite introduced into at least one of the two or more multiple zones is adsorbed onto a water-insoluble adsorbent;

(b) the well treatment agent of the composite introduced into at least one of the two or more multiple zones is immobilized on a support;

(c) the well treatment agent of the composite introduced into at least one of the two or more multiple zones is immobilized within a matrix;

or

(d) the well treatment agent of the composite introduced into at least one of the two or more multiple zones is immobilized on or within a porous particulate.

24. The method of claim 22, wherein at least one of the following conditions prevail:

(a) the transported fluid is flowback water and the zone of the subterranean formation from which the flowback water originated is determined by detecting the taggant of the well treatment agent in the flowback water by a physical or a chemical detection method;

(b) the transported fluid is produced water and the zone of the subterranean formation from which the produced water originated is determined by detecting the taggant of the well treatment agent in the produced water by a physical or chemical detection method;

(c) the transported fluid is gas or oil produced from the subterranean formation and further wherein the zone of the subterranean formation from which the produced gas or oil originated is determined by detecting the taggant of the well treatment agent in the produced gas or oil by a physical or chemical detection method.