Apparatus and methods for applying time lapse VSP to monitor a reservoir

• US 6,715,551 B2
• Filed: 06/19/2001
• Issued: 04/06/2004
• Est. Priority Date: 06/19/2000
• Status: Expired due to Term

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Cornish, Bruce E., Curtis, Michael P., Maerefat, Nicida L.
• Primary Examiner(s): SCHOEPPEL, ROGER J
• Application Number:
  US09/885,454
• Publication Number:
  US 20020053430A1
• Time in Patent Office: 1,022 Days
• Field of Search: 166/250.16, 166/64, 166/113, 166/244.1, 166/53, 166/63, 166/243, 166/249, 166/250.01, 166/254.1, 364/143, 364/147, 364/150, 364/151
• US Class Current: 166/250.16
• CPC Class Codes: G01V 1/282 Application of seismic models, synthetic seismograms
• CPC Class Codes: G01V 1/42 using generators in one well and receivers elsewhere or vice versa G01V1/52 takes precedence
• CPC Class Codes: G01V 2210/161 Vertical seismic profiling [VSP]
• CPC Class Codes: G01V 2210/612 Previously recorded data, e.g. time-lapse or 4D

Abstract

Subterranean reservoir monitoring method, computer system with programming code for implementing the method, and computer readable media and data signal embodying such programming code, the method including one or more of: (a) reservoir screening; (b) reservoir modeling; (c) generating model seismic data from a model; (d) model modification based on current VSP data; (e) repeating step (c) and step (d) until differences between the model and VSP data are as desired; (f) obtaining model production data from a reservoir model, and if necessary modifying the model and returning to step (c); (g) generating seismic model data for time t; and (h) comparing seismic model data with actual seismic data for time t, and if necessary modify the reservoir model and return to step (f) or modify the model of the subteranean and return to step (c).

Claims

1. A method for modeling a reservoir in the subterrane, comprising the steps of:

(a) screening the reservoir to determine if the reservoir comprises at least one property suitable for applying time lapse vertical seismic profiling, selected from the group consisting of geologic properties, fluid properties, dry rock properties and saturated rock properties; and

(b) if the reservoir is found to comprise at least one property suitable for applying time lapse vertical seismic profiling, initially modeling the reservoir to determine if vertical seismic profiling of the reservoir over time will provide suitable time variant response;

(c) if the initial modeling of the reservoir is found to include an observable time variant response, determining whether it is economically viable to apply time lapse vertical seismic profiling to the reservoir; and

(d) if determined to be economically viable, applying time lapse vertical seismic profiling to the reservoir, wherein applying time lapse vertical seismic profiling includes;

(e) generating model seismic data from a model of the subterrane;

(f) modifying the model of the subterrane based on a comparison of the model seismic data to current vertical seismic profile data to create a modified model of the subterrane, wherein the modified model then becomes the model of the subterrane; and

(g) repeating steps (e) and (f) until the difference between the model seismic data and the current vertical seismic profile data is minimized to a desired level.

2. The method of claim 1, further comprising:

(h) generating model seismic data at a first point in time from the model of the subterrane;

(i) comparing the model seismic data with actual seismic data for the first point in time; and

(j) if the differences are not as desired, modifying the model of the subterrane and repeating step (e) through (g).

3. The method of claim 1, further comprising:

(h) obtaining model production data from a reservoir model derived from the model of the subterrane;

(i) if the difference between the model production data and actual production data are not as desired, modifying the model of the subterrane, wherein the modified model then becomes the model of the subterrane; and

(j) repeating steps (h) and (i) until the difference between the model production data and the actual production data is minimized to a desired level.

4. The method of claim 3, further comprising:

(k) generating model seismic data at a first point in time from the model of the subterrane;

(l) comparing the model seismic data with actual seismic data for the first point in time; and

(m) if the differences are not as desired, modifying the reservoir model and repeating step (h) through (j).

5. A method for modeling a reservoir in the subterrane, comprising the steps of:

(a) screening the reservoir to determine if the reservoir comprises at least one property suitable for applying time lapse vertical seismic profiling, selected from the group consisting of geologic properties, fluid properties, dry rock properties and saturated rock properties;

(b) if the reservoir is found to comprise at least one property suitable for applying time lapse vertical seismic profiling, initially modeling the reservoir to determine if vertical seismic profiling of the reservoir over time will provide suitable time variant response;

(c) if the initial modeling of the reservoir is found to include an observable time variant response, determining whether it is economically viable to apply time lapse vertical seismic profiling to the reservoir; and

(d) if determined to be economically viable, applying time lapse vertical seismic profiling to the reservoir.

6. The method of claim 5, wherein the initial modeling of the reservoir includes:

generating a plurality of initial reservoir models for different points in time;

generating data sets from the initial reservoir models at the different points in time;

comparing the data sets to determine if there are observable differences with respect to time; and

if there are no observable differences in the data sets, determining that the reservoir is not suitable for applying time lapse vertical seismic profiling.

7. The method of claim 5, wherein applying time lapse vertical seismic profiling includes:

(e) generating model seismic data from a model of the subterrane;

(f) modifying the model of the subterrane based on a comparison of the model seismic data to current vertical seismic profile data to create a modified model of the subterrane, wherein the modified model then becomes the model of the subterrane; and

(g) repeating steps (e) and (f) until the difference between the model seismic data and the current vertical seismic profile data is minimized to a desired level.

8. The method of claim 7, further comprising:

(h) obtaining model production data from a reservoir model derived from the model of the subterrane;

(i) if the difference between the model production data and actual production data are not as desired, modifying the model of the subterrane, wherein the modified model then becomes the model of the subterrane; and

(j) repeating steps (h) and (i) until the difference between the model production data and the actual production data is minimized to a desired level.

9. The method of claim 8, further comprising:

(k) generating model seismic data at a first point in time from the model of the subterrane;

(l) comparing the model seismic data with actual seismic data for the first point in time; and

(m) if the differences are not as desired, modifying the reservoir model and repeating steps (h) through (j).

10. The method of claim 7, further comprising:

(h) generating model seismic data at a first point in time from the model of the subterrane;

(i) comparing the model seismic data with actual seismic data for the first point in time; and

(j) if the differences are not as desired, modifying the model of the subterrane and repeating steps (e) through (g).

11. The method of claim 5, wherein the screening step includes:

using a geological evaluation module to evaluate facies and reservoir geometry data from the reservoir and generate an output;

using a fluid evaluation module to evaluate fluid physical properties and production history data from the reservoir and generate an output;

using a rock matrix module to evaluate dry rock physics and dry rock physical properties data from the reservoir and generate an output; and

using a saturated rock properties module to evaluate saturated rock properties and saturated rock physics data from the reservoir and generate an output.

12. The method of claim 11, wherein the outputs from the geological evaluation module, the fluid evaluation module, the rock matrix module, and the saturated rock properties module are sent to a geophysical response evaluation module to inquire into an expected physical response of the reservoir.

13. The method of claim 12, wherein the outputs from the geological evaluation module, the fluid evaluation module, the rock matrix module, the saturated rock properties module, and the geophysical response evaluation module are analyzed to produce an overall screening score for the reservoir to indicate suitability for applying time lapse vertical seismic profiling to the reservoir.

14. The method of claim 5, wherein the screening step comprises:

evaluating facies and reservoir geometry of the reservoir, wherein the evaluation results in a output from a geological evaluation module; and

determining from the outputs if the facies and reservoir geometry of the reservoir justify application of time lapse vertical seismic profiling to the reservoir.

15. The method of claim 5, wherein the screening step comprises:

evaluating fluid physical properties and production history of the reservoir, wherein the evaluation results in a output from a fluid evaluation module; and

determining from the output if the fluid physical properties and production history of the reservoir justify application of time lapse vertical seismic profiling to the reservoir.

16. The method of claim 5, wherein the screening step comprises:

evaluating dry rock properties of the reservoir, wherein the evaluation results in a output from a rock matrix evaluation module; and

determining from the output if the dry rock properties of the reservoir justify application of time lapse vertical seismic profiling to the reservoir.

17. The method of claim 5, wherein the screening step comprises:

evaluating saturated rock physical properties of the reservoir, wherein the evaluation results in a output from a saturated rock properties module; and

determining from the output if the saturated rock physical properties of the reservoir justify application of time lapse vertical seismic profiling to the reservoir.

18. The method of claim 5, wherein the screening step further comprises:

utilizing a geophysical response evaluation module to inquire into an expected geophysical response of the reservoir;

determining whether differences in the expected geophysical response of the reservoir justify application of time lapse vertical seismic profiling to the reservoir.

19. The method of claim 5, wherein the modeling step comprises:

creating time-variable vertical seismic profiling data sets; and

determining if observable differences exist with respect to time in the generated vertical seismic profiling data sets.

20. The method of claim 19, wherein the vertical seismic profiling data sets are vertical seismic profiling amplitude variation with offset data sets.

21. A method for modeling a reservoir in the subterrane, comprising the steps of:

(a) screening the reservoir to determine if the reservoir comprises suitable geological properties, fluid properties, dry rock properties and saturated rock properties for applying time lapse vertical seismic profiling;

(b) if the reservoir is found to have suitable properties for applying time lapse vertical seismic profiling, initially modeling the reservoir to determine if vertical seismic profiling of the reservoir over time will provide suitable time variant response;

(c) if the initial modeling of the reservoir is found to include an observable time variant response, determining whether it is economically viable to apply time lapse vertical seismic profiling to the reservoir; and

(d) if determined to be economically viable, applying time lapse vertical seismic profiling to the reservoir.

22. The method of claim 21, wherein the screening step comprises:

evaluating facies and reservoir geometry of the reservoir, wherein the evaluation results in a output from a geological evaluation module;

evaluating fluid physical properties and production history of the reservoir, wherein the evaluation results in a output from a fluid evaluation module;

evaluating dry rock properties and dry rock physical properties of the reservoir, wherein the evaluation results in a output from a rock matrix evaluation module;

evaluating saturated rock physical properties of the reservoir, wherein the evaluation results in a output from a saturated rock properties module; and

determining from the outputs if the facies and reservoir geometry of the reservoir, the fluid physical properties and production history of the reservoir, the dry rock properties and dry rock physical properties of the reservoir, and the saturated rock physical properties of the reservoir justify application of time lapse vertical seismic profiling to the reservoir.

23. The method of claim 22, wherein the screening step further comprises:

utilizing a geophysical response evaluation module to inquire into an expected geophysical response of the reservoir;

determining whether differences in the expected geophysical response of the reservoir justify the application of time lapse vertical seismic profiling to the reservoir.

24. The method of claim 21, wherein the modeling step comprises:

creating time-variable vertical seismic profiling data sets; and

determining if there are observable differences with respect to time in the generated vertical seismic profiling data sets.

25. The method of claim 24, wherein the vertical seismic profiling data sets are vertical seismic profiling amplitude variation with offset data sets.

26. The method of claim 21, wherein the initial modeling of the reservoir includes:

generating a plurality of initial reservoir models for different points in time;

generating data sets from the initial reservoir models at the different points in time;

comparing the data sets to determine if there are observable differences with respect to time; and

if there are no observable differences in the data sets, determining that the reservoir is not suitable for applying time lapse vertical seismic profiling.

27. The method of claim 21, wherein applying time lapse vertical seismic profiling includes:

(e) generating model seismic data from a model of the subterrane;

(f) modifying the model of the subterrane based on a comparison of the model seismic data to current vertical seismic profile data to create a modified model of the subterrane, wherein the modified model then becomes the model of the subterrane; and

(g) repeating steps (e) and (f) until the difference between the model seismic data and the current vertical seismic profile data is minimized to a desired level.

28. The method of claim 27, further comprising:

(h) obtaining model production data from a reservoir model derived from the model of the subterrane;

(i) if the difference between the model production data and actual production data are not as desired, modifying the model of the subterrane, wherein the modified model then becomes the model of the subterrane; and

(j) repeating steps (h) and (i) until the difference between the model production data and the actual production data is minimized to a desired level.

29. The method of claim 28, further comprising:

(k) generating model seismic data at a first point in time from the model of the subterrane;

(l) comparing the model seismic data with actual seismic data for the first point in time; and

(m) if the differences are not as desired, modifying the reservoir model and repeating steps (h) through (j).

30. The method of claim 27, further comprising:

(h) generating model seismic data at a first point in time from the model of the subterrane;

(i) comparing the model seismic data with actual seismic data for the first point in time; and

(j) if the differences are not as desired, modifying the model of the subterrane and repeating steps (e) through (g).