Method and system of using a data weighted electromagnetic source for time-lapse monitoring of a reservoir production or hydraulic fracturing

Patent metadata

Field	Value
Publication number	US-9268052-B2
Application number	US-201213693082-A
Country	US
Kind code	B2
Filing date	Dec 4, 2012
Priority date	Dec 4, 2012
Publication date	Feb 23, 2016
Grant date	Feb 23, 2016

Abstract

A system and a method for time lapse monitoring of a target feature within a rock formation are provided. The system includes a data weighted electromagnetic source configured to generate an electromagnetic field in vicinity or at a surface of the rock formation; and an electromagnetic receiver configured to measure a component of the electromagnetic field generated by the source. The data weighted electromagnetic source includes a plurality of electromagnetic sources and an electromagnetic field contribution from each electromagnetic source is weighted so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver.

First claim

What is claimed is:

1. A system for time lapse monitoring of a target feature within a rock formation, the system comprising:
a data weighted electromagnetic source located on the rock formation at an earth's surface configured to generate an electromagnetic field that penetrates from the earth's surface to the target feature at depth within the rock formation; and
an electromagnetic receiver configured to measure a component of the electromagnetic field generated by the source wherein the component of the electromagnetic field contains information related to the target feature within the rock formation,
wherein the data weighted electromagnetic source includes a plurality of electromagnetic sources and an electromagnetic field contribution from each electromagnetic source is weighted so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver and wherein the weighting is done as S A (r, ω)=Σ n=1 N A n e −iφ n s(r,r n ,ω) where ω is the angular frequency of the signal s generated by each electromagnetic source n (n=1 . . . N), r is the position of the synthetic source, r n is the position of each electromagnetic source 1 . . . N, A n is the weighting amplitude of the electromagnetic signal generated by each electromagnetic source n, φ n is the phase of the electromagnetic signal generated by each electromagnetic source n.

2. The system according to claim 1 , wherein amplitude, phase or both of each electromagnetic field generated by each of the plurality of electromagnetic sources is selected so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver.

3. The system according to claim 1 , wherein in-phase and out-of-phase of the imaginary part of each electromagnetic field generated by each of the plurality of electromagnetic sources is selected so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver.

4. The system according to claim 1 , further comprising a processor configured to calculate a difference between a component of electromagnetic field measured at a first point in time and a component of electromagnetic field measured at a second point in time after the first point in time to determine a change in a characteristic of the target feature within the rock formation.

5. The system according to claim 4 , wherein the target feature includes an oil reservoir, a gas reservoir, or a fracture.

6. The system according to claim 5 , wherein a change in the characteristic of the target feature includes a fluid volume change in the oil or gas reservoir from a before production or a before injection state to an after production or an after injection state or change of the fracture by hydro-fracturing from a before hydro-fracturing state to an after hydro-fracturing state.

7. The system according to claim 1 , further comprising a processor configured to perform an inversion process on the component of the electromagnetic field measured by the electromagnetic receiver to obtain an enhanced image of the target feature.

8. The system according to claim 7 , wherein the processor is configured to perform the inversion process by using a sampling based stochastic algorithm where the measured component of electromagnetic field is used in a likelihood function or a deterministic gradient based inversion algorithm where the measured component of electromagnetic field is used in an object function.

9. The system according to claim 1 , wherein the plurality of electromagnetic sources include a plurality of electric dipole sources.

10. The system according to claim 1 , wherein the plurality of electromagnetic sources include a plurality of magnetic field sources.

11. The system according to claim 1 , wherein the electromagnetic receiver includes one or more electric field receivers.

12. The system according to claim 1 , wherein the electromagnetic receiver includes one or more magnetic field receivers.

13. The system according to claim 1 , wherein the electromagnetic receiver is configured to measure the component of the electromagnetic field before production or before injection in a reservoir or before hydro-fracturing the rock formation to obtain a first electromagnetic response, and to measure the component of the electromagnetic field after production, or after injection in the reservoir or after hydro-fracturing the rock formation to obtain a second electromagnetic response.

14. The system according to claim 13 , wherein hydro-fracturing the rock formation includes injecting an electrically conductive fluid into the rock formation to increase an electrical conductivity of the rock formation by displacing less electrically conductive fluids that naturally exist within the rock formation wherein the increase in the electrical conductivity is designed to be greater than a noise level in the component of the electromagnetic field.

15. The system according to claim 13 , wherein hydro-fracturing the rock formation includes injecting a magnetically enhanced fluid into the rock formation to increase its magnetic susceptibility by displacing less magnetically susceptible material or fluids that naturally exist within the rock formation wherein the increase in the magnetic susceptibility is designed to be greater than a noise level in the component of the electromagnetic field.

16. The system according to claim 13 , further comprising a processor configured to compute a percent change from the first and second electromagnetic response.

17. A method for time lapse monitoring of a target feature within a rock formation, the method comprising:
generating an electromagnetic field that penetrates from an earth's surface to the target feature at depth within the rock formation using a data weighted electromagnetic source located on the rock formation at the earth's surface, the data weighted electromagnetic source including a plurality of electromagnetic sources;
measuring a component of the electromagnetic field generated by the source using an electromagnetic receiver wherein the component of the electromagnetic field contains information related to the target feature within the rock formation; and
weighting an electromagnetic field contribution from each electromagnetic source so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver wherein the weighting is done as S A (r, ω)=Σ n=1 N A n e −iφ n s(r,r n ,ω) where ω is the angular frequency of the signal s generated by each electromagnetic source n (n=1 . . . N), r is the position of the synthetic source, r n is the position of each electromagnetic source 1 . . . N, A n is the weighting amplitude of the electromagnetic signal generated by each electromagnetic source n, φ n is the phase of the electromagnetic signal generated by each electromagnetic source n.

18. The method according to claim 17 , further comprising selecting amplitude, phase or both of each electromagnetic field generated by each of the plurality of electromagnetic sources so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver.

19. The method according to claim 17 , further comprising selecting in-phase and out-of-phase of the imaginary part of each electromagnetic field generated by each of the plurality of electromagnetic sources so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver.

20. The method according to claim 17 , further comprising calculating a

Assignees

• Hoversten Gary Michael
• Brown Vanessa Claire
• Alumbaugh David Lee
• Chevron Usa Inc

Inventors

• Hoversten Gary Michael
• Brown Vanessa Claire
• Alumbaugh David Lee

Classifications

• G01V3/38

  Processing data, e.g. for analysis, for interpretation, for correction · CPC title

• G01V2003/084

  Sources · CPC title

• G01V3/083 Primary

  Controlled source electromagnetic [CSEM] surveying · CPC title

• G01V3/12 Primary

  operating with electromagnetic waves {(operating with millimetre waves G01V8/005)} · CPC title

• G01V2003/086

  Processing · CPC title