US4156464A
Expired / Lapsed
US
⏱️ 0.0 years remaining
Combined fracturing process for stimulation of oil and gas wells
Assignee: Canadian Fracmaster Ltd
•
Filing: 1978-06-05
•
Granted: 1979-05-29
•
Expires: 1998-06-05
Abstract
Abstract The present invention relates to a method of forming fractures and placing proppants therein, which comprises creating a foam having a down-well Mitchell quality of form about 0.53 to 0.99 and passing that foam down the well in admixture with a particulate proppant in an amount of up to four pounds of proppant per gallon of foam, then decreasing the gas volume in said foam, whereby the proppant carrying medium being passed down the well changes from a foam to a liquid. The proppant concentration is decreased as the change occurs from foam to liquid so that the proppant material will not deposit out prematurely in the well. Once liquid flow has been established, the proppant to fluid ratio is gradually increased and the fracture of the formation is continued with liquid and proppant. The liquid is capable of carrying an amount of proppant greater than that which could be carried by the foam, namely an amount up to twelve pounds per U.S. gallon.
Inventors
- 👤 Clint Hussin
Bibliographic Details
Application Number
—
Jurisdiction
US
Data Source
google_patents
Last Synchronized
2026-10-26 21:47
CPC Classifications
E; E21; E21B; E21B43/00; E21B43/25; E21B43/26; E21B43/267; C; C09; C09K; C09K8/00; C09K8/60; C09K8/62; C09K8/70; C09K8/703
Claims Analysis
Total Claims: 18
Claim 1
Independent Claim
150 words
A process of fracturing a well to increase the rate of hydrocarbon yield thereof, which comprises; forming a foam of a Mitchell quality at the level of the formation to be treated of from 0.53 to 0.99; performing a foam fracture treatment on the well with said foam, said foam carrying in suspension during at least part of the fracture treatment, a proppant allowing the foam to remain the well under pressure; prior to allowing the foam to escape, introducing into the well a liquid fracturing agent under pressure, said liquid fracturing agent being introduced in a volume greater than the volume of the well, whereby to pressurize the foam and increase the volume of the fracture in the formation, said liquid fracturing agent including, for at least a portion of the time during which it is introduced, from one to twelve pounds of proppant per U.S. gallon of liquid.
Claim 2
Dependent Claim
150 words
A process of fracturing a well to increase the rate of hydrocarbon yield thereof, which comprises; forming a foam of a Mitchell quality at the level of the formation to be treated of from 0.53 to 0.99; performing a foam fracture treatment on the well with said foam, said foam carrying in suspension during at least part of the fracture treatment, a proppant allowing the foam to remain the well under pressure; prior to allowing the foam to escape, introducing into the well a liquid fracturing agent under pressure, said liquid fracturing agent being introduced in a volume greater than the volume of the well, whereby to pressurize the foam and increase the volume of the fracture in the formation, said liquid fracturing agent including, for at least a portion of the time during which it is introduced, from one to twelve pounds of proppant per U.S. gallon of liquid.
Claim 3
Dependent Claim
40 words
A process as claimed in claim 1, wherein the gas component of said foam consists of a gas selected from the group consisting of nitrogen, carbon dioxide, air, natural gas, and combustion exhaust gas, and non-explosive mixtures from such gases.
Claim 4
Dependent Claim
27 words
A process according to claim 2, wherein the proppant material is selected from the group consisting of sand, crushed rock, crushed glass, glass beads and nut hulls.
Claim 5
Dependent Claim
31 words
A process as claimed in claim 1, wherein the liquid component of said foam comprises at least one liquid selected from the group consisting of water and a liquid hydrocarbon fraction.
Claim 6
Dependent Claim
14 words
The method of claim 1, wherein the liquid component of the foam is water.
Claim 7
Dependent Claim
21 words
A process as claimed in claim 1, in which the foam is formed of nitrogen, a conventional foaming agent, and water.
Claim 8
Dependent Claim
26 words
A process as claimed in claim 6, in which the water in said foam was included therein a reagent capable of reacting with the well formation.
Claim 9
Dependent Claim
15 words
A process as claimed in claim 6, in which the liquid fracturing agent is water.
Claim 10
Dependent Claim
36 words
A process as claimed in claim 8, in which said water which is present as the liquid fracturing agent includes a conventional foaming agent and sufficient gas to lightly aerate the water without forming a foam.
Claim 11
Dependent Claim
13 words
A process as claimed in claim 9, in which the gas is nitrogen.
Claim 12
Dependent Claim
30 words
A process as claimed in claim 10, in which the nitrogen which is present to aerate the water is present in an amount of up to 300 standard cubic feet.
Claim 13
Dependent Claim
16 words
A process as claimed in claim 11, in which the foaming agent is sodium lauryl sulfate.
Claim 14
Dependent Claim
28 words
A method as claimed in claim 1, wherein the liquid component of said foam is water having a solution therein an acid capable of reacting with said formation.
Claim 15
Dependent Claim
26 words
A process as claimed in claim 13, in which the liquid fracturing agent is an aqueous solution of an acid capable of reacting with the formation.
Claim 16
Dependent Claim
29 words
A process as claimed in claim 14, in which the acid present in the liquid fracturing agent is selected from the group consisting of hydrochloric, acetic and formic acids.
Claim 17
Dependent Claim
29 words
A process as claimed in claim 1, in which the amount of proppant present in the foam does not exceed four pounds of proppant per U.S. gallon of foam.
Claim 18
Dependent Claim
19 words
A process as claimed in claim 1, in which the liquid component is a mixture of water and methanol.
References Cited (Backward Citations)
US2859821A
Cited
US2965172A
Cited
US3063499A
Cited
US3136361A
Cited
US3195634A
Cited
US3245470A
Cited
US3335794A
Cited
US3572440A
Cited
US3980136A
Cited
US3937283A
Cited
US4044833A
Cited
USPTO Annuity & Maintenance Windows
| Annuity Stage | Window Opens | Payment Deadline | Surcharge Period Until | Estimated Fee | Status |
|---|---|---|---|---|---|
| 3.5 Years (Year 4) | 1982-05-28 | 1982-11-27 | 1983-05-29 | $2000.00 | Window Closed / Lapsed |
| 7.5 Years (Year 8) | 1986-05-28 | 1986-11-27 | 1987-05-29 | $3760.00 | Window Closed / Lapsed |
| 11.5 Years (Year 12) | 1990-05-28 | 1990-11-27 | 1991-05-29 | $7700.00 | Window Closed / Lapsed |