US4186802A
Expired / Lapsed
US
⏱️ 0.0 years remaining
Fracing process
Assignee: Individual
•
Filing: 1978-03-13
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Granted: 1980-02-05
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Expires: 1998-03-13
Abstract
Abstract A method for hydraulically fracturing a single subterranean formation in which a fracture is first induced in the formation and then subjected to multiple hydraulic fracturing cycles to generate vertical linear fractures or to linearly extend the fracture outward from the point of introduction of the fracing fluid into a well penetrating the formation. By utilizing fracing fluid containing a high ratio of fine proppant and injected at a low rate, the linear fracturing solely within the formation can be substantially increased with very little or no radial vertical fracturing occurring outside the formation.
Inventors
- 👤 William Perlman
Bibliographic Details
Application Number
—
Jurisdiction
US
Data Source
google_patents
Last Synchronized
2026-10-29 10:44
CPC Classifications
E; E21; E21B; E21B43/00; E21B43/25; E21B43/26; E21B43/267
Claims Analysis
Total Claims: 25
Claim 1
Independent Claim
150 words
A method of forming vertical linear fractures in a subterranean producing formation extending outwardly from a well penetrating the formation without forming any substantial radial vertical fracturing of overlying or underlying strata, comprising the steps of introducing, in a multiplicity of stages a proppant laden fracing fluid carrying a fine-sized proppant material in an average proppant-to-fluid ratio of at least eight pounds per gallon, introducing between said stages of proppant laden fracing fluid a spacer stage of fracing fluid without proppant, said proppant laden fracing fluid and said spacer fracing fluid being injected at an injection rate below 25 barrels per minute and at a pressure selected for producing said vertical linear fracture in the formation, said introduction of said proppant laden fracing fluid continuing until at least 25,000 pounds of said fine proppant material have been deposited in the formation fracture for each one-foot of available net producing formation.
Claim 2
Independent Claim
150 words
A method of forming vertical linear fractures in a subterranean producing formation extending outwardly from a well penetrating the formation without forming any substantial radial vertical fracturing of overlying or underlying strata, comprising the steps of introducing, in a multiplicity of stages a proppant laden fracing fluid carrying a fine-sized proppant material in an average proppant-to-fluid ratio of at least eight pounds per gallon, introducing between said stages of proppant laden fracing fluid a spacer stage of fracing fluid without proppant, said proppant laden fracing fluid and said spacer fracing fluid being injected at an injection rate below 25 barrels per minute and at a pressure selected for producing said vertical linear fracture in the formation, said introduction of said proppant laden fracing fluid continuing until at least 25,000 pounds of said fine proppant material have been deposited in the formation fracture for each one-foot of available net producing formation.
Claim 3
Dependent Claim
49 words
The method described in claim 1, wherein a terminal stage of said fracing fluid carrying a medium-sized proppant material in a proppant-to-fluid ratio less than said fine-sized proppant material proppant-to-fluid ratio is introduced into said fractures for depositing said medium-sized proppant material in the formation adjacent the well bore.
Claim 4
Dependent Claim
15 words
The method described in claim 1, wherein said fine-sized proppant material is 60-140 mesh sand.
Claim 5
Dependent Claim
15 words
The method described in claim 2, wherein said medium-sized proppant material is 20-90 mesh sand.
Claim 6
Dependent Claim
50 words
The method described in claim 1, wherein said fracing fluid is a combination of KCl water, gel and alcohol, and the volume of alcohol combined with said KCl water to form the total volume of said fracing fluid is preselected from the range of 25% to 70% alcohol by volume.
Claim 7
Dependent Claim
25 words
The method described in claim 1, wherein said fracing fluid injection rate is selected from within the range of 2 to 20 barrels per minute.
Claim 8
Dependent Claim
30 words
The method described in claim 1, wherein said fine-sized proppant material proppant-to-fluid ratio is selected from the range of 8 to 20 pounds of proppant per gallon of fracing fluid.
Claim 9
Dependent Claim
23 words
The method disclosed in claim 1, wherein said fracing fluid is a combination of KCl water, gel, alcohol and liquified CO 2 .
Claim 10
Dependent Claim
70 words
The method disclosed in claim 8, wherein the volume of alcohol combined with said KCl water to form the total volume of said fracing fluid is preselected from the range of 25% to 70% alcohol by volume, and the volume of CO 2 combined with said KCl water to form said total volume of fracing fluid is preselected from the range of 10% to 20% liquified CO 2 by volume.
Claim 11
Dependent Claim
25 words
The method disclosed in claim 9, wherein said carrier stage injection rate is selected from within the range of 2 to 20 barrels per minute.
Claim 12
Dependent Claim
30 words
The method disclosed in claim 9, wherein said fine-sized proppant material proppant-to-fluid ratio is selected from the range of 8 to 20 pounds of proppant per gallon of fracing fluid.
Claim 13
Independent Claim
177 words
A method of forming vertical linear fractures in a subterranean producing formation extending outwardly from a well penetrating the formation without forming any substantial radial vertical fracturing of overlying or underlying strata, comprising the steps of introducing a plurality of carrier stages of fracing fluid carrying a fine-sized proppant material in an average proppant-to-fluid ratio of at least eight pounds per gallon, said carrier stage fracing fluid being injected at an injection rate below 25 barrels per minute and at a pressure selected for producing the fractures in the formation, introducing a plurality of spacer stages of said fracing fluid, alternating with said carrier stages, at a selected pressure and rate sufficient to carry said carrier stage proppant material into said fracture and away from said well, and introducing a terminal stage of said fracing fluid carrying a medium-sized proppant material in a proppant-to-fluid ratio less than said carrier stage ratio, said terminal stage being injected at a selected pressure and rate sufficient to carry said terminal stage sand into said fractures adjacent said injection well bore.
Claim 14
Independent Claim
177 words
A method of forming vertical linear fractures in a subterranean producing formation extending outwardly from a well penetrating the formation without forming any substantial radial vertical fracturing of overlying or underlying strata, comprising the steps of introducing a plurality of carrier stages of fracing fluid carrying a fine-sized proppant material in an average proppant-to-fluid ratio of at least eight pounds per gallon, said carrier stage fracing fluid being injected at an injection rate below 25 barrels per minute and at a pressure selected for producing the fractures in the formation, introducing a plurality of spacer stages of said fracing fluid, alternating with said carrier stages, at a selected pressure and rate sufficient to carry said carrier stage proppant material into said fracture and away from said well, and introducing a terminal stage of said fracing fluid carrying a medium-sized proppant material in a proppant-to-fluid ratio less than said carrier stage ratio, said terminal stage being injected at a selected pressure and rate sufficient to carry said terminal stage sand into said fractures adjacent said injection well bore.
Claim 15
Dependent Claim
15 words
The method described in claim 12, wherein said fine-sized proppant material is 60-140 mesh sand.
Claim 16
Dependent Claim
15 words
The method described in claim 13, wherein said medium-sized proppant material is 20-40 mesh sand.
Claim 17
Dependent Claim
50 words
The method described in claim 12, wherein said fracing fluid is a combination of KCl water, gel and alcohol, and the volume of alcohol combined with said KCl water to form the total volume of said fracing fluid is preselected from the range of 25% to 70% alcohol by volume.
Claim 18
Dependent Claim
24 words
The method described in claim 12, wherein said carrier stage injection rate is selected from the range of 2 to 20 barrels per minute.
Claim 19
Dependent Claim
29 words
The method described in claim 12, wherein said carrier stage proppant-to-fluid ratio is selected from the range of 8 to 20 pounds of proppant per gallon of fracing fluid.
Claim 20
Dependent Claim
45 words
The method disclosed in claim 12, wherein introduction of said carrier stages is continued to achieve a proppant volume of at least 25,000 pounds of said fine-sized proppant material deposited into the formation fracture for each one-foot of vertical net pay zone of the formation.
Claim 21
Dependent Claim
23 words
The method disclosed in claim 12, wherein said fracing fluid is a combination of KCl water, gel, alcohol and liquified CO 2 .
Claim 22
Dependent Claim
70 words
The method disclosed in claim 19, wherein the volume of alcohol combined with said KCl water to form the total volume of said fracing fluid is preselected from the range of 25% to 70% alcohol by volume, and the volume of CO 2 combined with said KCl water to form said total volume of fracing fluid is preselected from the range of 10% to 20% liquified CO 2 by volume.
Claim 23
Dependent Claim
24 words
The method disclosed in claim 20, wherein said carrier stage injection rate is selected from the range of 2 to 20 barrels per minute.
Claim 24
Dependent Claim
29 words
The method disclosed in claim 20, wherein said carrier stage proppant-to-fluid ratio is selected from the range of 8 to 20 pounds of proppant per gallon of fracing fluid.
Claim 25
Dependent Claim
43 words
The method disclosed in claim 22, wherein introduction of said carrier stages is continued to achieve a proppant volume of 25,000 pounds of said fine-sized proppant material deposited into the formation fracture for each one-foot of vertical net pay zone of the formation.
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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) | 1983-02-04 | 1983-08-06 | 1984-02-05 | $2000.00 | Window Closed / Lapsed |
| 7.5 Years (Year 8) | 1987-02-04 | 1987-08-06 | 1988-02-05 | $3760.00 | Window Closed / Lapsed |
| 11.5 Years (Year 12) | 1991-02-04 | 1991-08-06 | 1992-02-05 | $7700.00 | Window Closed / Lapsed |