CA2675823A1 - Hydraulic fracture initiation and propagation control in unconsolidated and weakly cemented sediments - Google Patents

Hydraulic fracture initiation and propagation control in unconsolidated and weakly cemented sediments Download PDF

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Publication number
CA2675823A1
CA2675823A1 CA002675823A CA2675823A CA2675823A1 CA 2675823 A1 CA2675823 A1 CA 2675823A1 CA 002675823 A CA002675823 A CA 002675823A CA 2675823 A CA2675823 A CA 2675823A CA 2675823 A1 CA2675823 A1 CA 2675823A1
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Canada
Prior art keywords
fracture
formation
fluid
foam
casing
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CA002675823A
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French (fr)
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CA2675823C (en
Inventor
Grant Hocking
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GeoSierra LLC
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Geosierra Llc
Grant Hocking
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Publication of CA2675823A1 publication Critical patent/CA2675823A1/en
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    • CCHEMISTRY; METALLURGY
    • C09DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09KMATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60Compositions for stimulating production by acting on the underground formation
    • C09K8/62Compositions for forming crevices or fractures
    • C09K8/70Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
    • C09K8/703Foams
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25Methods for stimulating production
    • E21B43/26Methods for stimulating production by forming crevices or fractures
    • E21B43/267Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping

Abstract

A method and apparatus for initiating and propagating a vertical hydraulic fracture in unconsolidated and weakly cemented sediments from a single bore hole to control the fracture initiation plane and propagation of the hydraulic fracture, enabling greater yield and recovery of petroleum fluids from the formation. An injection casing with multiple fracture initiation sections is inserted and grouted into a bore hole. A foam fracture fluid carrying a proppant is injected into the injection casing and opens the fracture initiation sections to dilate the formation in a direction orthogonal to the required fracture azimuth plane. Propagation of the fracture is controlled by limiting the fracture fluid form to that of a stable foam fracturing fluid during the fracturing process. The injection casing initiation section remains open after fracturing providing direct hydraulic connection between the production well bore, the permeable proppant filled fracture and the formation.

Claims (44)

1. A method for creating a vertical hydraulic fracture in a formation of unconsolidated and weakly cemented sediments, comprising:

a. drilling a bore hole in the formation to a predetermined depth;

b. installing an injection casing in the bore hole at the predetermined depth;

c. dilating the injection casing and the formation in a preferential direction; and, d. injecting a foam fracture fluid into the injection casing with sufficient fracturing pressure to initiate a vertical fracture at an azimuth orthogonal to the direction of dilation
2. The method of Claim 1, wherein the method further comprises:

a. installing the injection casing at a predetermined depth in the bore hole, wherein an annular space exists between the outer surface of the casing and the bore hole, b. filling the annular space with a grout that bonds to the outer surface of the casing, wherein the casing has multiple initiation sections separated by a weakening line so that the initiation sections either separate, open, yield or stretch across the weakening line.
3. The method of Claim 2, wherein the foam fracture fluid dilates the casing, grout annulus and the formation to initiate the fracture in the formation at a weakening line.
4. The method of Claim 2, wherein a mandrel dilates the casing, grout annulus and the formation and the foam fracture fluid initiates the fracture in the formation at a weakening line.
5. The method of Claim 2, wherein an expanding tool or packer dilates the casing, grout annulus and the formation and the foam fracture fluid initiates the fracture in the formation at a weakening line.
6. The method of Claim 1, wherein the foam fracture fluid is a polymer based foam fracturing fluid with either CO2 or N2 or a combination thereof to form the gaseous phase.
7. The method of claim 1, wherein the foam fracture fluid is a non-polymer based foam fracturing fluid with either CO2 or N2 or a combination thereof to form the gaseous phase.
8. The method of Claim 1, wherein the foam fracture fluid comprises a proppant.
9. The method of Claim 1, wherein the fracture fluid comprises a proppant, and the foam fracture fluid is able to carry the proppant of the fracture fluid at low flow velocities.
10. The method of Claim 8, wherein the fracture fluid comprises a proppant which has a size ranging from #4 to #100 U.S. mesh, and the proppant is selected from a group consisting of sand, resin-coated sand, expoxy-coated sand, ceramic beads, synthetic organic beads, glass microspheres, resin coated proppant and sintered minerals.
11. The method of Claim 1, wherein the foam fracture fluid comprises a proppant and a proppant flowback-retention agent.
12. The method of Claim 11, wherein the fracture fluid comprises a proppant flowback-retention agent, which is selected from a group consisting of natural organic fibers, synthetic organic fibers, glass fibers, carbon fibers, ceramic fibers, inorganic fibers, and metal fibers.
13. The method of Claim 1, wherein the fracture fluid is clean breaking with minimal residue.
14. The method of Claim 1, wherein the fracture fluid has a low friction coefficient.
15. The method of Claim 1, wherein the fracture fluid injection rate, pressure and proppant loading is selected so as to promote a screening out of the fracture at the tip to create a wide fracture.
16. The method of Claim 1, wherein the casing system enables controlling the rate of fracture fluid injection into each individual opposing wing of the initiated and propagating hydraulic fracture thereby controlling the geometry of the hydraulic fracture.
17. The method of Claim 2, wherein the initiation sections do not close following completion of hydraulic fracturing to provide hydraulic connection of the fracture with the well bore.
18. The method of Claim 1, wherein the method further comprises re-fracturing of each previously injected fracture.
19. The method of Claim 2, wherein the casing comprises two initiation sections with two directions of dilation.
20. The method of Claim 2, wherein the casing comprises two initiation sections with two directions of dilation and the first and second weakening lines are orthogonal.
21. The method of Claim 19, wherein the casing system enables controlling the rate of fracture fluid injection into each individual opposing wing of the initiated and propagating hydraulic fractures thereby controlling the geometry of the hydraulic fractures.
22. The method of Claim 19, wherein the initiation sections do not close following completion of hydraulic fracturing to provide hydraulic connection of the fracture with the well bore.
23. The method of Claim 2, wherein the casing comprises three initiation sections with three directions of dilation.
24. The method of Claim 23, wherein the casing system enables controlling the rate of fracture fluid injection into each individual opposing wing of the initiated and propagating hydraulic fractures thereby controlling the geometry of the hydraulic fractures.
25. The method of Claim 23, wherein the initiation sections do not close following completion of hydraulic fracturing to provide hydraulic connection of the fracture with the well bore.
26. The method of Claim 2, wherein the casing comprises four initiation sections with four directions of dilation, with the first and second weakening lines being orthogonal to each other and the third and fourth weakening lines being orthogonal to each other.
27. The method of Claim 26, wherein the casing system enables controlling the rate of fracture fluid injection into each individual opposing wing of the initiated and propagating hydraulic fractures thereby controlling the geometry of the hydraulic fractures.
28. The method of Claim 26, wherein the initiation sections do not close following completion of hydraulic fracturing to provide hydraulic connection of the fracture with the well bore.
29. The method of Claim 1, wherein the dilation of the formation is achieved by first cutting a vertical slot in the formation at the required azimuth for the initiated fracture, injecting a fracture fluid into the slot with a sufficient fracturing pressure to dilate the formation in this preferential direction and thereby initiate a vertical fracture at an azimuth orthogonal to the direction of dilation; and controlling the form of the fracturing fluid to be a foam based fracturing fluid.
30. A well in a formation of unconsolidated and weakly cemented sediments, comprising a bore hole in the formation to a predetermined depth; an injection casing in the bore hole at the predetermined depth; a source for delivering a fracture fluid into the injection casing with sufficient fracturing pressure to dilate the injection casing and the formation and initiate a vertical fracture with a fracture tip at an azimuth orthogonal to the direction of dilation, wherein the injection casing further comprises:

a. multiple initiation sections separated by a weakening line and b. multiple passages within the initiation sections and communicating across the weakening line for the introduction of the fracture fluid to dilate the casing and separate the initiation sections along the weakening line, wherein the passages to each opposing wing of the fracture are connected to the source of fracture fluid to dilate the formation in a preferential direction and thereby initiate the vertical fracture at the azimuth orthogonal to the direction of dilation and to control the propagation rate of each individual opposing wing of the hydraulic fracture, and the source delivers the fracture fluid in the form of a stable foam during the fracturing process.
31. The well of Claim 30, wherein the foam fracture fluid is a polymer based foam fracturing fluid with either CO2 or N2 or a combination thereof to form the gaseous phase.
32. The well of Claim 30, wherein the foam fracture fluid is a non-polymer based foam fracturing fluid with either CO2 or N2 or a combination thereof to form the gaseous phase.
33. The well of Claim 30, wherein the foam fracture fluid comprises a proppant.
34. The well of Claim 30, wherein the foam fracture fluid comprises a proppant, and the fracture fluid is able to carry the proppant of the fracture fluid at low flow velocities.
35. The well of Claim 34, wherein the foam fracture fluid comprises a proppant which has a size ranging from #4 to #100 U.S. mesh, and the proppant is selected from a group consisting of sand, resin-coated sand, exopy-coated sand, ceramic beads, synthetic organic beads, glass microspheres, resin coated proppant and sintered minerals.
36. The well of Claim 30, wherein the foam fracture fluid comprises a proppant and a proppant flowback-retention agent.
37. The well of Claim 36, wherein the fracture fluid comprises a proppant flowback-retention agent, which is selected from a group consisting of natural organic fibers, synthetic organic fibers, glass fibers, carbon fibers, ceramic fibers, inorganic fibers, and metal fibers.
38. The well of Claim 30, wherein the foam fracture fluid is clean breaking with minimal residue.
39. The well of Claim 30, wherein the foam fracture fluid has a low friction coefficient.
40. The well of Claim 30, wherein the foam fracture fluid injection rate, pressure, and proppant loading is selected so as to promote a screening out of the fracture at the tip to create a wide fracture.
41. The well of Claim 30, wherein the initiation sections do not close following completion of hydraulic fracturing to provide hydraulic connection of the fracture with the well bore.
42. The well of Claim 30, wherein the method further comprises re-fracturing of each previously injected fracture.
43. A well in a formation of unconsolidated and weakly cemented sediments, comprising a bore hole in the formation to a predetermined depth; an injection casing in the bore hole at the predetermined depth, the injection casing comprising multiple initiation sections separated by a weakening line, passages within the initiation sections communicate a fracture fluid to each opposing wing of a selected weakening line, wherein each weakening line corresponds to one of a plurality of fracture planes;
and a source for delivering the fracture fluid with sufficient pressure to dilate the formation, and initiate a fracture with a fracture tip in the formation along the desired fracture plane, and controlling the form of the fracture fluid to be a stable foam during the fracturing process.
44. A well in a formation of unconsolidated and weakly cemented sediments, comprising a bore hole in the formation to a predetermined depth; an injection casing in the bore hole at the predetermined depth, the injection casing comprising multiple initiation sections separated by a weakening line, passages within the initiation sections communicate a fracture fluid to each opposing wing of a selected opposed pair of weakening lines, wherein each opposed pair of weakening lines corresponds to one of a plurality of desired fracture planes; and a source for delivering the fracture fluid with sufficient pressure to dilate the formation, and initiate a fracture with a fracture tip in the formation along the desired fracture plane, and controlling the form of the fracture fluid to be a stable foam during the fracturing process.
CA2675823A 2007-03-15 2008-03-13 Hydraulic fracture initiation and propagation control in unconsolidated and weakly cemented sediments Expired - Fee Related CA2675823C (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US11/686,425 2007-03-15
US11/686,425 US7866395B2 (en) 2006-02-27 2007-03-15 Hydraulic fracture initiation and propagation control in unconsolidated and weakly cemented sediments
PCT/US2008/056758 WO2008112837A2 (en) 2007-03-15 2008-03-13 Hydraulic fracture initiation and propagation control in unconsolidated and weakly cemented sediments

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CA2675823A1 true CA2675823A1 (en) 2008-09-18
CA2675823C CA2675823C (en) 2012-11-20

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Also Published As

Publication number Publication date
WO2008112837A9 (en) 2009-03-26
US7866395B2 (en) 2011-01-11
US20070199708A1 (en) 2007-08-30
WO2008112837A3 (en) 2009-01-22
CA2675823C (en) 2012-11-20
WO2008112837A2 (en) 2008-09-18

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