PHASED STIMULATION METHODS
A method of stimulating a subterranean formation is provided. The method includes determining a final fracture spacing. The method includes creating a first set of fractures at a first fracture spacing, the first fracture spacing being larger than the final fracture spacing. The method includes allowing production of fluids from the formation through the well bore via the first set of fractures for a period of time. The method includes, after the period of time, creating a second set of fractures. The final fracture spacing is less than or equal to an average fracture spacing between the first set of fractures and the second set of fractures.
This application claims the benefit of U.S. Provisional Application No. 61/879,886, filed on Sep. 19, 2013, which is incorporated herein by reference.
FIELD OF THE INVENTIONThe present disclosure relates generally to stimulation of subterranean formations and more particularly to a method of phased stimulation.
BACKGROUNDHydrocarbon (e.g., oil, natural gas, etc.) reservoirs may be found in subterranean formations that have little to no porosity (e.g., shale, tight sandstone etc.). The hydrocarbons may be trapped within fractures and pore spaces of the formation. Additionally, the hydrocarbons may be adsorbed onto organic material of the shale formation. The rapid development of extracting hydrocarbons from these unconventional reservoirs can be tied to the combination of horizontal drilling and hydraulic fracturing. Horizontal drilling has allowed for drilling along and within hydrocarbon reservoirs to better capture the hydrocarbons trapped therein. Additionally, more hydrocarbons may be captured by increasing the number of fractures in the formation and/or increasing the size of already present fractures through fracturing or other stimulation.
The spacing between fractures as well as the ability to stimulate the fractures naturally present in the rock may be major factors in the success of horizontal completions in unconventional hydrocarbon reservoirs. Effective placement of fractures in deviated or horizontal wells is challenging. This challenge is highlighted in formations with low permeability. As permeability decreases, smaller spacing is generally necessary to effectively recover hydrocarbons from the formation. However, as the spacing between fractures decreases, the stresses associated with the injection of fluids into the formation to create one fracture is believed to create a “shadow” stress in the formation that negatively influences the placement of the next fracture.
SUMMARY OF THE INVENTIONIn one embodiment, a method of stimulating a subterranean formation is provided. The method includes determining a final fracture spacing. The method includes creating a first set of fractures at a first fracture spacing, the first fracture spacing being larger than the final fracture spacing. The method includes allowing production of fluids from the formation through the well bore via the first set of fractures for a period of time. The method includes, after the period of time, creating a second set of fractures. The final fracture spacing is less than or equal to an average fracture spacing between the first set of fractures and the second set of fractures.
In an embodiment, a method of phased stimulation of a zone in a subterranean formation is provided. The method includes stimulating the zone via a first set of fractures originating at a well bore and having a first fracture spacing. The method includes allowing primary production from the zone via the first set of fractures. The method includes providing isolation between the first set of fractures and the well bore before the primary production reaches a predetermined threshold. The method includes further stimulating the zone via a second set of fractures originating at the wellbore, wherein at least one of the fractures of the second set of fractures lies between adjacent fractures in the first set of fractures. The method includes allowing production from the zone via the second set of fractures. The method includes removing the isolation between the first set of fractures and the well bore thereby allowing secondary production from the zone via the first set of fractures.
Referring now to the figures,
One method of stimulating a subterranean formation 10 having a well bore 12 therein includes (1) determining a threshold stress value indicative of presence of a stress shadow (e.g., by field or other estimations based on formation characteristics), (2) obtaining a formation stress value (e.g., by measurements taken onsite, by field estimations, by calculations, or otherwise), (3) allowing production from the subterranean formation 10 when the stress shadow is present (i.e., when the measured stress value exceeds the threshold stress value), and (4) ceasing production when the stress shadow has dissipated (i.e, when the measured stress value drops below the threshold stress value).
The first step of the method of
Referring now to
The production of fluids 32 is believed to relieve the pore pressure thus relieving the stress in the rock over time. By allowing fluid 32 to leave the formation 10, it is thought that the stresses caused by fracturing may be alleviated in the region around such fractures. Such reduction in stresses may allow for a superior fracture to be created between existing fractures, as compared to fractures created without allowing for such stress relief. Thus, production of fluids 32 may be permitted until a predetermined threshold is reached. In one example, the predetermined threshold may be a time of production from the formation 10. While allowing for a large time to pass might provide for more stress relief, it is thought that the period of time for production between formation of the first set of fractures 21, 22, 23 and formation of the second set of fractures 24, 25 may be relatively short. Such period of time might be less than a year, from 6 months to a year, from 1 to 6 months, from 1 week to 1 month, or from 1 hour to 1 week. In some instances, the period of time might be as small as a few days or even within a few hours. An alternate predetermined threshold may be a percentage of a maximum projected production from the formation 10. While allowing for a large percentage of the maximum projected production might provide for more stress relief, it is thought that the production between formation of the first set of fractures 21, 22, 23 and formation of the second set of fractures 24, 25 may be relatively small. Such production might be less than 50% of the maximum projected production, less than 25% of the maximum projected production, less than 5% of the maximum projected production, or less than 1% of the maximum projected production. In some instances, the production may be as small as a tenths of a percent or even a few hundredths of a percent. Other alternatives to time and production volumes may be used in the embodiments described, so long as some method of feedback on whether sufficient relief of the stress caused by a particular set of fractures has occurred via production.
Once the stress created by the first set of fractures 21, 22, 23 has been relieved, the production of fluid 32 from the formation 10 via the first set of fractures 21, 22, 23 may be stopped by plugging the fractures 21, 22, 23, or otherwise providing isolation between the first set of fractures 21, 22, 23 and the well bore 12. Such isolation may be provided through any of a number of methods. For example, as illustrated in
Referring now to
As illustrated in
The second period of time might be determined based on providing sufficient time to permit the relief of stress created by the second set of fractures 24, 25. Such period of time might be less than a year. For example, the second period of time might be anywhere between 1 and 6 months. In some instances, the second period of time might be as small as a few days or even a few hours. Once the stress created by the second set of fractures 24, 25 has been relieved, the production of fluid 32 from the formation 10 via the second set of fractures 24, 25 may be stopped by plugging the fractures 24, 25, or otherwise providing isolation between the second set of fractures 24, 25 and the well bore 12.
Referring now to
As illustrated in
A method of phased stimulation of the zone 14 in the subterranean formation 10 can also be described with respect to
The primary production from the zone 14 via the first set of fractures 21, 22, 23 is less than the production from zone 14 via both the first and second sets of fractures 21-25. Likewise, if a third set of fractures 26-29 is provided, the production from the combined first second and third set of fractures is greater than the production from the first and second sets of fractures. Thus, the primary production from the zone 14 is less than a maximum production from the zone 14. Further, the primary production from the zone 14 may be less than a maximum economical production from the zone. Such maximum economical production from the zone 14 might be less than the maximum production available from the zone 14, but might represent the most profitable amount of production when accounting for costs involved. Generally, the primary production from the zone 14 will be less than the maximum economical production. However, it is thought that the sacrifice of maximum economical production in the primary production is outweighed by the benefit provided by superior communication with the zone 14 via the second set of fractures 24, 25, the optional third set of fractures 26-29, and any additional iterations provided by repeating the process.
Similarly, after the processes described herein, any of the fractures may be re-stimulated in a secondary or remedial operation. In such a process, a set of fractures may be created, stimulated, and may produce before being isolated while another set of fractures is stimulated. Then, both sets of fractures may produce for some time before either or both sets of fractures is re-stimulated and may produce once again. Furthermore, methods analogous to those above could be used for operations involving other formation treatments. For example, matrix stimulation may benefit from methods such as those described herein.
Those of skill in the art will appreciate that many modifications and variations are possible in terms of the disclosed embodiments, configurations, materials, and methods without departing from their scope. Accordingly, the scope of the claims and their functional equivalents should not be limited by the particular embodiments described and illustrated, as these are merely exemplary in nature and elements described separately may be optionally combined.
Claims
1. A method of stimulating a subterranean formation having a well bore therein, the method comprising:
- determining a final fracture spacing;
- creating a first set of fractures at a first fracture spacing, the first fracture spacing being larger than the final fracture spacing;
- allowing production of fluids from the formation through the well bore via the first set of fractures for a period of time;
- after the period of time, creating a second set of fractures;
- wherein the final fracture spacing is less than or equal to an average fracture spacing between the first set of fractures and the second set of fractures.
2. The method of claim 1, wherein the first fracture spacing is at least double the final fracture spacing.
3. The method of claim 1, wherein the final fracture spacing comprises an economically optimized fracture spacing, and wherein the step of determining the final fracture spacing comprises determining the economically optimized fracture spacing.
4. The method of claim 1, wherein the period of time comprises sufficient time to permit the relief of stress created by the first set of fractures.
5. The method of claim 1, wherein the period of time comprises less than one year.
6. The method of claim 5, wherein the period of time comprises from 1 month to 6 months.
7. The method of claim 5, wherein the period of time comprises from 1 week to 1 month.
8. The method of claim 5, wherein the period of time comprises from 1 hour to 1 week.
9. The method of claim 1, further comprising stopping production of fluids from the first set of fractures prior to creating the second set of fractures.
10. The method of claim 1, further comprising:
- allowing production of fluids from the formation through the well bore via the second set of fractures for a second period of time;
- after the second period of time, creating a third set of fractures;
- wherein the final fracture spacing is less than or equal to an average fracture spacing between the first set of fractures, the second set of fractures, and the third set of fractures.
11. A method of phased stimulation of a zone in a subterranean formation, the method comprising:
- stimulating the zone via a first set of fractures originating at a well bore and having a first fracture spacing;
- allowing primary production from the zone via the first set of fractures;
- providing isolation between the first set of fractures and the well bore before the primary production reaches a predetermined threshold;
- further stimulating the zone via a second set of fractures originating at the wellbore, wherein at least one of the fractures of the second set of fractures lies between adjacent fractures in the first set of fractures;
- allowing production from the zone via the second set of fractures; and
- removing the isolation between the first set of fractures and the well bore thereby allowing secondary production from the zone via the first set of fractures.
12. The method of claim 11, wherein the predetermined threshold comprises a percentage of a maximum projected production from the zone.
13. The method of claim 12, wherein the percentage is no more than 50%.
14. The method of claim 13, wherein the percentage is no more than 25%.
15. The method of claim 14, wherein the percentage is no more than 5%.
16. The method of claim 11, wherein the predetermined threshold comprises a time of production from the zone.
17. The method of claim 16, wherein the time of production is no more than 1 year.
18. The method of claim 11, wherein the first set of fractures and the second set of fractures have an average fracture spacing and wherein the first fracture spacing is at least twice the average fracture spacing.
19. The method of claim 11, wherein the first fracture spacing is at least four times a final fracture spacing.
20. The method of claim 11, wherein the step of providing isolation comprises running tubing with external packers into the well bore.
21. The method of claim 11, further comprising re-stimulating the first set of fractures.
22. A method comprising:
- (a) determining a threshold stress value indicative of presence of a stress shadow;
- (b) obtaining a formation stress value;
- (c) allowing production when the formation stress value exceeds the threshold stress value; and
- (d) ceasing production when the formation stress value drops below the threshold stress value.
23. The method of claim 22 further comprising:
- before step (c), stimulating a zone in a subterranean formation via a first set of fractures originating at a well bore;
- providing isolation between the first set of fractures and the well bore before the production reaches the threshold stress value;
- further stimulating the zone via a second set of fractures originating at the wellbore, wherein at least one of the fractures of the second set of fractures lies between adjacent fractures in the first set of fractures;
- allowing production from the zone via the second set of fractures; and
- removing the isolation between the first set of fractures and the well bore thereby allowing secondary production from the zone via the first set of fractures.
Type: Application
Filed: Sep 17, 2014
Publication Date: Mar 19, 2015
Inventors: Ernesto Rafael FONSECA OCAMPOS (Houston, TX), Anastasia DOBROSKOK (Houston, TX)
Application Number: 14/488,733
International Classification: E21B 43/26 (20060101); E21B 43/14 (20060101); E21B 33/12 (20060101);