US3958638A
Expired / Lapsed
US
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Method for altering the permeability of a subterranean formation
Assignee: Phillips Petroleum Co
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Filing: 1975-06-16
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Granted: 1976-05-25
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Expires: 1995-06-16
Abstract
Abstract A method for altering the permeability of a subterranean formation in which aqueous polymer solution and encapsulated reacting agent is passed into the formation with subsequent release of reacting agent in response to formation conditions causing a reaction that thickens the polymer solution.
Inventors
- 👤 Chester C. Johnston
Bibliographic Details
Application Number
—
Jurisdiction
US
Data Source
google_patents
Last Synchronized
2026-11-06 02:58
CPC Classifications
C; C09; C09K; C09K8/00; C09K8/50; C09K8/504; C09K8/506; C09K8/508; C09K8/514; C09K8/02; C09K8/04; C09K8/06; C09K8/12; C09K8/516
Claims Analysis
Total Claims: 16
Claim 1
Independent Claim
121 words
A method for altering the permeability of a subterranean hydrocarbon-containing formation penetrated by at least one wellbore, comprising: 1. passing aqueous polymer solution into the formation, said polymer capable of reaction to increase the viscosity of the aqueous polymer solution; 2. passing into the formation a gelation agent which is in an encapsulating material and which is capable of reaction with said polymer to increase the viscosity thereof, said encapsulating material capable of releasing the gelation agent in situ in response to the temperature of the subterranean formation; and 3. subjecting said encapsulating material to a temperature sufficient to release said gelation agent whereby contact between the gelation agent and aqueous polymer solution increases the viscosity of the aqueous polymer solution.
Claim 2
Independent Claim
121 words
A method for altering the permeability of a subterranean hydrocarbon-containing formation penetrated by at least one wellbore, comprising: 1. passing aqueous polymer solution into the formation, said polymer capable of reaction to increase the viscosity of the aqueous polymer solution; 2. passing into the formation a gelation agent which is in an encapsulating material and which is capable of reaction with said polymer to increase the viscosity thereof, said encapsulating material capable of releasing the gelation agent in situ in response to the temperature of the subterranean formation; and 3. subjecting said encapsulating material to a temperature sufficient to release said gelation agent whereby contact between the gelation agent and aqueous polymer solution increases the viscosity of the aqueous polymer solution.
Claim 3
Dependent Claim
23 words
A method of claim 1 wherein said gelation agent is an oxidizing agent and a reducing agent is also present in subterranean formation.
Claim 4
Dependent Claim
22 words
A method of claim 2 wherein said gelation agent is an oxidizing agent and the subterranean formation contains naturally occurring hydrogen sulfide.
Claim 5
Dependent Claim
25 words
A method of claim 3 wherein the oxidizing agent is a polyvalent metal compound wherein the metal has a valence reducible to a lower valence.
Claim 6
Dependent Claim
34 words
A method of claim 4 wherein the oxidizing agent is present in an amount sufficient to provide at least 3 × 10 - 6 gram atoms of the polyvalent metal per gram of polymer.
Claim 7
Dependent Claim
23 words
A method of claim 1 wherein said gelation agent is a reducing agent and an oxidizing agent is present in the subterranean formation.
Claim 8
Dependent Claim
20 words
A method of claim 1 wherein the gelation agent comprises a mixture of encapsulated oxidizing agent and encapsulated reducing agent.
Claim 9
Dependent Claim
19 words
A method of claim 1 wherein the encapsulating material is one of paraffin wax, polyethylene, polypropylene or mixtures thereof.
Claim 10
Dependent Claim
25 words
A method of claim 1 wherein the gelation agent is a polyvalent metal compound wherein the metal has a valence reducible to a lower valence.
Claim 11
Dependent Claim
34 words
A method of claim 9 wherein the oxidizing agent is one of potassium permanganate, sodium permanganate, ammonium chromate, ammonium dichromate, an alkali metal chromate, an alkali metal dichromate, chromium trioxide or a mixture thereof.
Claim 12
Dependent Claim
34 words
A method of claim 9 wherein the oxidizing agent is present in an amount sufficient to provide at least 10 × 10 - 6 gram atoms of the polyvalent metal per gram of polymer.
Claim 13
Dependent Claim
13 words
A method of claim 1 wherein the reducing agent is a sulfur-containing compound.
Claim 14
Dependent Claim
21 words
A method of claim 12 wherein the reducing agent is one of sodium hydrosulfite, potassium hydrosulfite, sodium bisulfite or mixtures thereof.
Claim 15
Dependent Claim
39 words
A method of claim 1 wherein the amount of reducing agent is in the range of about 0.1 percent to about 200 percent of the stoichiometric amount of reducing agent necessary to lower the valence of the oxidizing agent.
Claim 16
Dependent Claim
21 words
A method of claim 1 wherein said polymer solution comprises at least one of cellulose ethers, polyacrylamides, polysaccharides, and mixtures thereof.
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USPTO Annuity & Maintenance Windows
| Annuity Stage | Window Opens | Payment Deadline | Surcharge Period Until | Estimated Fee | Status |
|---|---|---|---|---|---|
| 3.5 Years (Year 4) | 1979-05-25 | 1979-11-24 | 1980-05-25 | $2000.00 | Window Closed / Lapsed |
| 7.5 Years (Year 8) | 1983-05-25 | 1983-11-24 | 1984-05-25 | $3760.00 | Window Closed / Lapsed |
| 11.5 Years (Year 12) | 1987-05-25 | 1987-11-24 | 1988-05-25 | $7700.00 | Window Closed / Lapsed |