Estimating well production performance in fractured reservoir systems

Patent metadata

Field	Value
Publication number	US-9732592-B2
Application number	US-201414648852-A
Country	US
Kind code	B2
Filing date	Aug 1, 2014
Priority date	Aug 1, 2014
Publication date	Aug 15, 2017
Grant date	Aug 15, 2017

Abstract

Systems and methods for estimating well production performance in fractured reservoir systems using real-time down-hole temperature and stress information from advanced monitoring techniques.

First claim

The invention claimed is:

1. A method for identifying poor fracture conductivity in fractured reservoir systems to use in refracturing, which comprises:
a) sampling an average effective fracture length from a distribution of average effective fracture lengths;
b) selecting current pressure and temperature profiles over a length of each fracture stage;
c) performing history matching to determine a misfit using the current pressure and temperature profiles, the distribution of average effective fracture lengths, the sampled average effective fracture length and a computer processor;
d) updating a static well model using the current pressure and temperature profiles, the distribution of average effective fracture lengths and the sampled average effective fracture length for the static well model;
e) calculating a fracture conductivity for each fracture stage;
f) selecting pressure and temperature profiles for a predetermined period of time over the length of each fracture stage;
g) performing history matching using at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of any effective fracture lengths, the sampled average effective fracture length and the computer processor;
h) updating the updated static well model, which represents a new updated static well model, using the at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of average effective fracture lengths and the sampled average effective fracture length for the updated static well model;
i) calculating a Reynolds number for each fracture stage based on the new updated static well model; and
j) identifying each fracture stage with poor fracture conductivity using at least one of the fracture conductivity and the Reynolds number calculated for each fracture stage.

2. The method of claim 1 , further comprising refracturing a reservoir system based on a fracture stage with at least one of the fracture conductivity less than about 1 millidarcy-feet and the Reynolds number greater than about 1.

3. The method of claim 1 , further comprising repeating steps a)-c) until the misfit is acceptable.

4. The method of claim 3 , wherein the misfit is minimized with each iteration of steps a)-c).

5. The method of claim 3 , wherein the misfit is acceptable at less than about 10% deviation.

6. The method of claim 1 , wherein the fracture conductivity for each fracture stage is calculated using a total flow rate and a mass flow rate for each fracture stage.

7. The method of claim 1 , wherein the static well model is represented by standard reservoir properties, complex reservoir properties, complex fracture network properties, production data profiles and standard well completion and simulation properties.

8. A non-transitory program carrier device tangibly carrying computer-executable instructions for identifying poor fracture conductivity in fractured reservoir systems to use in refracturing, the instructions being executable to implement:
a) sampling an average effective fracture length from a distribution of average effective fracture lengths;
b) selecting current pressure and temperature profiles over a length of each fracture stage;
c) performing history matching to determine a misfit using the current pressure and temperature profiles, the distribution of average effective fracture lengths, the sampled average effective fracture length;
d) updating a static well model using the current pressure and temperature profiles, the distribution of average effective fracture lengths and the sampled average effective fracture length for the static well model;
e) calculating a fracture conductivity for each fracture stage;
f) selecting pressure and temperature profiles for a predetermined period of time over the length of each fracture stage;
g) performing history matching using at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of any effective fracture lengths, the sampled average effective fracture length;
h) updating the updated static well model, which represents a new updated static well model, using the at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of average effective fracture lengths and the sampled average effective fracture length for the updated static well model;
i) calculating a Reynolds number for each fracture stage based on the new updated static well model; and
j) identifying each fracture stage with poor fracture conductivity using at least one of the fracture conductivity and the Reynolds number calculated for each fracture stage.

9. The program carrier device of claim 8 , further comprising refracturing a reservoir system based on a fracture stage with at least one of the fracture conductivity less than about 1 millidarcy-feet and the Reynolds number greater than about 1.

10. The program carrier device of claim 8 , further comprising repeating steps a)-c) until the misfit is acceptable.

11. The program carrier device of claim 10 , wherein the misfit is minimized with each iteration of steps a)-c).

12. The program carrier device of claim 10 , wherein the misfit is acceptable at less than about 10% deviation.

13. The program carrier device of claim 8 , wherein the fracture conductivity for each fracture stage is calculated using a total flow rate and a mass flow rate for each fracture stage.

14. The program carrier device of claim 8 , wherein the static well model is represented by standard reservoir properties, complex reservoir properties, complex fracture network properties, production data profiles and standard well completion and simulation properties.

15. A method for identifying poor fracture conductivity in fractured reservoir systems to use in refracturing, which comprises:
a) selecting acoustic profiles for a predetermined period of time over a length of each fracture stage;
b) calculating a compressional velocity using at least one of the acoustic profiles;
c) identifying a main lithology of an acoustic medium represented by the acoustic profiles and a related Gardner coefficient;
d) calculating an effective stress using the compressional velocity and the Gardner coefficient;
e) calculating a fracture conductivity for each fracture stage using the effective stress and a computer processor; and
f) identifying each fracture stage with poor fracture conductivity.

16. The method of claim 15 , further comprising refracturing a reservoir system based on a fracture stage with at least one of the fracture conductivity less than about 1 millidarcy-feet and the Reynolds number greater than about 1.

17. The method of claim 15 , wherein the main lithology of the acoustic medium is identified using a lithology log generated in a static well model.

18. A non-transitory program carrier device tangibly carrying computer-executable instructions for identifying poor fracture conductivity in fractured reservoir systems to use in refracturing, the instructions being executable to implement:
a) selecting acoustic profiles for a predetermined period of time over a length of each fracture stage;
b) calculating a compressional velocity using at least one of the acoustic profiles;
c) identifying a main lithology of an acoustic medium represented by the acoustic profiles and a related Gardn

Assignees

• Landmark Graphics Corp

Inventors

• Carvajal Gustavo
• Khoriakov Vitaly
• Flippov Andrey
• Maucec Marko
• Diaz Arturo
• Knabe Steven

Classifications

• E21B47/06 Primary

  Measuring temperature or pressure · CPC title

• E21B49/00

  Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells · CPC title

• G01V2210/1234

  Hydrocarbon reservoir, e.g. spontaneous or induced fracturing · CPC title

• G01V2210/61

  Analysis by combining or comparing a seismic data set with other data · CPC title

• E21B43/26

  by forming crevices or fractures · CPC title