Increasing fracture complexity in ultra-low permeable subterranean formation using degradable particulate

• US 8,853,137 B2
• Filed: 01/31/2011
• Issued: 10/07/2014
• Est. Priority Date: 07/30/2009
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Todd, Bradley L., Welton, Thomas D.
• Primary Examiner(s): Li, Aiqun
• Application Number:
  US13/017,611
• Publication Number:
  US 20120024530A1
• Time in Patent Office: 1,345 Days
• Field of Search: 507/203, 507/260, 507/922, 507/924, 166/308.1, 166/280.1
• US Class Current: 507/260
• CPC Class Codes: C09K 8/03 Specific additives for general use in well-drilling compositions
• CPC Class Codes: C09K 8/516 characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: C09K 8/536 characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: C09K 8/72 Eroding chemicals, e.g. acids
• CPC Class Codes: C09K 8/80 Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
• CPC Class Codes: C09K 8/92 characterised by their form or by the form of their components, e.g. encapsulated material C09K8/70 takes precedence
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping
• CPC Class Codes: Y10S 507/922 Fracture fluid
• CPC Class Codes: Y10S 507/924 with specified propping feature

Abstract

A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%. Similar methods using stepwise fracturing fluids and remedial fracturing treatments are provided.

Claims

1. A method of increasing the fracture complexity in a treatment zone of a subterranean formation, wherein the treatment zone is an interval of rock along a wellbore that is differentiated from surrounding rocks based on hydrocarbon content, fluid communication with the wellbore, faults, or fractures, wherein the subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy, the method comprising the step of:

pumping two or more fracturing fluids into the treatment zone at a rate and pressure above the fracture pressure of the treatment zone for a total pumping volume of the two or more fracturing fluids pumped into the treatment zone that is greater than 2 wellbore volumes, wherein;

(a) a first fracturing fluid of the two or more fracturing fluids is pumped into the treatment zone at least before the last 2 wellbore volumes of the total pumping volume, wherein the first fracturing fluid comprises a proppant, wherein the first fracturing fluid does not include a first solid particulate; and

(b) a second fracturing fluid of the two or more fracturing fluids is pumped into the treatment zone after the first fracturing fluid is pumped into the treatment zone but at least before the last 2 wellbore volumes of the total pumping volume, wherein the second fracturing fluid comprises the first solid particulate;

wherein the first solid particulate comprises a first particle size range effective for bridging the pore throats of a proppant pack formed in the treatment zone by the proppant of the first fracturing fluid, wherein the first particle size range has a lower end that is greater than or equal to about 1/13^th of the median particle size of the proppant, and

wherein the first solid particulate is degradable.

2. The method according to claim 1, wherein the degradable material is a degradable polymer.

3. The method according to claim 2, wherein the degradable polymer has hydrolyzable or oxidizable linkages in the backbone.

4. The method according to claim 2, wherein the degradable polymer is selected from the group consisting of:

poly(hydroxy alkanoate);

poly(alpha-hydroxy) acids;

poly(beta-hydroxy alkanoates);

poly(omega-hydroxy alkanoates);

poly(alkylene dicarboxylates);

polyanhydrides;

poly(orthoesters);

polycarbonates;

poly(dioxepan-2-one);

aliphatic polyesters;

poly(lactides);

poly(glycolides);

poly(e-c aprolactones);

poly(hydroxybutyrates);

poly(anhydrides);

aliphatic polycarbonates;

poly(orthoesters);

poly(amino acids);

poly(ethylene oxides); and

polyphosphazenes.

5. The method according to claim 2, wherein the degradable polymer is selected from the group consisting of polyesters and polyanhydrides.

6. The method according to claim 2, wherein the degradable polymer comprises a poly(lactide).

7. The method according to claim 1, wherein the first solid particulate is in at least a sufficient amount in the first fracturing fluid to reduce the permeability of at least a region of the proppant pack at least 50%.

8. The method according to claim 1, wherein the first fracturing fluid has a viscosity in the range of about 0.7 cP to about 10 cP.

9. The method according to claim 1, wherein the proppant of the proppant pack has a graded particle size range anywhere between −

70/+140U.S. Standard Mesh.

10. The method according to claim 1, wherein the first particle size range has an upper end that is less than or equal to about ⅙

^th of the median size of the proppant.

11. The method according to claim 10, wherein the proppant of the proppant pack is equal to or less than 100 U.S. Standard Mesh.

12. The method according to claim 1, wherein the first solid particulate comprises a second particle size range effective for bridging the pore throats of the first solid particulate.

13. The method according to claim 1, wherein the first fracturing fluid comprises a second solid particulate, wherein the second solid particulate has a second particle size range effective for bridging the pore throats of the first solid particulate.

14. The method according to claim 13, wherein the second solid particulate is degradable.

15. The method according to claim 1, further comprising the step of:

after pumping the two or more fracturing fluids into the treatment zone, allowing or causing the first solid particulate to degrade.

16. The method according to claim 1, further comprising:

determining microseismic activity to confirm an increase in fracture complexity in the treatment zone.

17. The method according to claim 1, further comprising repeating the step of pumping in another treatment zone of the subterranean formation.

18. The method according to claim 1, wherein the second fracturing fluid comprises the proppant.

19. The method according to claim 1, wherein the first particulate consists essentially of the degradable material.

20. The method according to claim 1, wherein the first particulate consists of the degradable material.