Method of calibrating fracture geometry to microseismic events

Patent metadata

Field	Value
Publication number	US-10352145-B2
Application number	US-201414896685-A
Country	US
Kind code	B2
Filing date	Jul 2, 2014
Priority date	Mar 11, 2011
Publication date	Jul 16, 2019
Grant date	Jul 16, 2019

Abstract

A method of performing a fracture operation is provided at a wellsite. The wellsite is positioned about a subterranean formation having a wellbore therethrough and a complex fracture network therein. The complex fracture network includes natural fractures, and the wellsite stimulated by injection of an injection fluid with proppant into the complex fracture network. The method involves generating wellsite data comprising measurements of microseismic events of the subterranean formation, modeling a hydraulic fracture network and a discrete fracture network of the complex fracture network based on the wellsite data, and performing a seismic moment operation. The method involves determining an actual seismic moment density based on the wellsite data and a predicted seismic moment density based on shear and tensile components of the simulated hydraulic fracture network, and calibrating the discrete fracture network based on a comparison of the predicted moment density and the actual moment density.

First claim

What is claimed is:

1. A method of performing a fracture operation at a wellsite, the wellsite positioned about a subterranean formation having a wellbore ( 1204 ) therethrough and a complex fracture network therein, the fracture network comprising natural fractures, the wellsite stimulated by injection of an injection fluid with proppant into the fracture network, the method comprising:
generating wellsite data ( 2352 ) comprising measurements of microseismic events of the subterranean formation;
modeling ( 2375 ) a hydraulic fracture network and a discrete fracture network of the complex fracture network based on the wellsite data;
characterized in that the method further comprises:
performing ( 4553 . 2 ) a seismic moment operation, comprising:
determining ( 4559 ) an actual seismic moment density based on the wellsite data and a predicted seismic moment density based on shear and tensile components of the simulated hydraulic fracture network, wherein determining the predicted seismic moment density comprises defining ( 4557 ) the shear and tensile components of the simulated hydraulic fracture network and converting ( 4558 ) the shear and tensile components of the simulated hydraulic fracture network to a simulated moment density; and
calibrating ( 4561 ) the discrete fracture network based on a comparison of the predicted moment density and the actual moment density; and

adjusting ( 2387 ) the injection based on the calibrating.

2. The method of claim 1 , further comprising predicting ( 4567 ) proppant placement based on the modeled discrete fracture network.

3. The method of claim 2 , further comprising predicting ( 4568 ) production based on the predicted proppant placement.

4. The method of claim 2 , further comprising predicting ( 4569 ) reservoir pressure based on the predicted proppant placement.

5. The method of claim 1 , wherein modeling a discrete fracture network comprises generating an initial discrete fracture network from at least one of wellsite data comprising seismic measurement, geological structure, borehole imaging log, core, and combinations thereof based on description measurement.

6. The method of claim 1 , wherein modeling hydraulic fracture network comprises generating an initial hydraulic fracture design and carrying out simulation using a complex fracture model that incorporates the interaction of hydraulic fractures and natural fractures.

7. The method of claim 1 , wherein generating wellsite data comprises pumping fracturing treatment into a wellbore of the wellsite and collecting microseismic data in real-time.

8. The method of claim 1 , wherein calibrating comprises:
calibrating ( 4777 ) the discrete fracture network and redistributing the natural fractures according to an observed microseismic event distribution over an event area;
calibrating ( 4779 ) additional natural fracture and formation parameters using the calibrated discrete fracture network to match a coverage area of the modeled hydraulic fracture network against the event area and the simulated treatment pressure against a measured pressure; and
optimizing ( 4781 ) the injection at the wellsite by revising the modeled hydraulic fracture based on the calibrated discrete fracture network.

9. The method of claim 1 , further comprising performing a shear failure operation comprising:
determining ( 2377 ) a stress field of the hydraulic fractures using a geomechanical model;
determining ( 2379 ) shear failure parameters comprising a failure envelope and a stress state about the fracture network;
determining ( 2381 ) a location of shear failure of the fracture network from the failure envelope and the stress state; and
comparing ( 2383 ) the modeled hydraulic fractures and the locations of shear failure against the measured microseismic events.

10. The method of claim 1 , further comprising stimulating ( 2350 ) the wellsite by injecting the injection fluid with proppant into the fracture network.

11. The method of claim 10 , wherein adjusting comprises adjusting ( 2387 ) the stimulation operation based on the calibrating.

Assignees

• Schlumberger Technology Corp

Inventors

• Maxwell Shawn
• Weng Xiaowei
• Kresse Olga
• Cipolla Craig
• Mack Mark
• Rutledge James T
• Underhill William
• Ganguly Utpal

Classifications

• E21B43/267 Primary

  reinforcing fractures by propping · CPC title