Multi-stage fracture injection process for enhanced resource production from shales

• US 8,978,764 B2
• Filed: 12/22/2011
• Issued: 03/17/2015
• Est. Priority Date: 12/22/2010
• Status: Active Grant

• Current Assignee: Maurice B. Dusseault, Roman Bilak
• Original Assignee: Maurice B. Dusseault, Roman Bilak
• Inventors: Dusseault, Maurice B., Bilak, Roman
• Primary Examiner(s): MICHENER, BLAKE E
• Application Number:
  US13/578,810
• Publication Number:
  US 20130284438A1
• Time in Patent Office: 1,181 Days
• Field of Search: 166/400, 166/271, 166/280.1, 166/280.2, 1663081-3086, 166/177.5
• US Class Current: 166/308.1
• CPC Class Codes: E21B 43/26 by forming crevices or fractures
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping

Abstract

The invention relates to a method of generating a network of fractures in a rock formation for extraction of hydrocarbon or other resource from the formation. The method includes the steps of i) enhancing a network of natural fractures and incipient fractures within the formation by injecting a non-slurry aqueous solution into the well under conditions suitable for promoting dilation, shearing and/or hydraulic communication of the natural fractures, and subsequently ii) inducing a large-fracture network that is in hydraulic communication with the enhanced natural fracture network by injecting a plurality of slurries comprising a carrying fluid and sequentially larger-grained granular proppants into said well in a series of injection episodes.

Claims

1. A method of generating an extended fracture network in a rock formation, said formation characterized by a network of native fractures and incipient fractures and a minimum hydraulic fracturing pressure and rate whereby fluid injected at a higher rate and pressure causes the formation to fracture, said method comprising the sequential steps of

i) injecting a non-slurry aqueous solution into the formation at a pressure and rate which is slightly above the minimum hydraulic fracturing pressure and rate whereby a zone of essentially self-propping fractures is generated by increased pore pressure, shearing, and dilation of the native fractures and incipient fractures, and wherein said step (i) is performed until the maximum possible stimulated volume of the formation has been substantially attained for a given injection site as determined by formation response measurement data;

ii) injecting a plurality of slurries comprising a carrying fluid and sequentially larger-grained granular proppants into said formation whereby said steps i and ii generate an inner zone of fractures that are propped with said granular proppant and at least some of the fractures therein are widened, and an outer zone surrounding the inner zone essentially comprising self-propped fractures; and

iii) further extending and propagating the outer zone by additional injection of non-slurry aqueous solution into the formation at a pressure and rate slightly above the minimum hydraulic fracturing pressure and rate.

2. The method of claim 1 wherein said steps ii and/or iii further comprising controlling and optimizing formation volume resulting from steps ii and/or iii in order to facilitate stress rotations and fracture rotations.

3. The method of claim 1 for extraction of one or more of crude oil, hydrocarbon gas or geothermal energy.

4. The method of claim 1 wherein said formation has a permeability of less than 10 milliDarcy.

5. The method of claim 1 wherein said aqueous non-slurry solution comprises water or saline that is essentially free of additives.

6. The method of claim 1 wherein step ii further comprises a sequence of discrete water injection episodes separated by episodes of injection of said proppant.

7. A method of generating an extended fracture network in a rock formation, said formation being characterized by a network of native fractures and incipient fractures and a minimum hydraulic fracturing pressure and rate whereby fluid injected at a higher rate and pressure causes the formation to fracture, said method comprising:

Stage 1;

injecting a non-slurry aqueous solution into said formation slightly above the minimum hydraulic fracturing pressure and rate whereby a zone of self-propping fractures is generated by increased pore pressure, shearing and dilation of the native fractures and incipient fractures, wherein said stage 1 is performed until the maximum possible stimulated volume of the formation has been substantially attained as determined by formation response measurement data;

Stage 2;

injecting a first slurry comprising a carrying fluid and a fine-grained granular proppant into said formation whereby said stage 2 generates an inner zone within the zone generated in stage 1 wherein fractures are propped with said fine-grained granular proppant; and

Stage 3;

injecting a second slurry comprising a coarse-grained proppant having a coarser grain than said fine-grained proppant into said formation, whereby at least a portion of the fractures within the inner zone are widened and propped with said coarse-grained proppant wherein said inner zone is surrounded by an outer zone comprising essentially self-propped fractures generated in said stage 1, said inner zone providing a pathway for additional non-slurry aqueous solution to further extend said outer zone.

8. The method of claim 7 comprising cycling sequentially for a plurality of cycles of stages 1, 2 and 3, or repeating any of stages 1, 2 or 3, or repeating any pair of stages 1, 2 or 3.

9. The method of claim 7 wherein said aqueous solution comprises water or saline that is essentially free of additives.

10. The method of claim 7 wherein stage 2 follows stage 1 with essentially no time gap.

11. The method of claim 7 wherein stage 2 and/or Stage 3 further comprises a sequence of discrete water injection episodes separated by episodes of injection of said granular or coarse-grained proppant.

12. The method of claim 7 comprising performing a plurality of cycles each comprising stages 1 through 3 and providing a shut-in period between said cycles.

13. The method of claim 7 wherein any one of stages 1-3 is repeated multiple times in sequence, or stage 1 is repeated following stage 3.

14. The method of claim 7 wherein said stages 2 and/or 3 are performed under conditions that favour generating and propagating increased volume within the formation.

15. The method of claim 7 for extraction of one or more of crude oil, hydrocarbon gas or geothermal energy.

16. The method of claim 7 wherein said formation has a permeability of less than 10 milliDarcy.