Onshore electromagnetic reservoir monitoring

• US 10,302,796 B2
• Filed: 11/26/2014
• Issued: 05/28/2019
• Est. Priority Date: 11/26/2014
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Wilson, Glenn A., Donderici, Burkay
• Primary Examiner(s): Bui, Bryan
• Application Number:
  US15/522,250
• Publication Number:
  US 20170322333A1
• Time in Patent Office: 1,644 Days
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons
• CPC Class Codes: G01H 9/004 using fibre optic sensors light guides per se G02B6/00, acousto-optical devices specially adapted for gating or modulating in optical wave guides G02F1/125
• CPC Class Codes: G01V 3/12 operating with electromagnetic waves operating with millimetre waves G01V8/005
• CPC Class Codes: G01V 8/02 Prospecting
• CPC Class Codes: G01V 8/24 using optical fibres
• CPC Class Codes: G01V 9/02 Determining existence or flow of underground water

Abstract

Onshore electromagnetic (EM) reservoir monitoring systems and methods, including a system with a light source producing a light beam and an EM sensor array positioned above ground or buried underground over one or more regions of interest within a subterranean formation, the array coupled to the light source with an optical fiber. An EM sensor modulates the interrogation light beam in response to an EM signal induced into the subterranean formation by an EM source. The system further includes a processor controlling the light source, processing modulated light received from the array, and collecting data with the array to produce EM surveys, each EM survey based on data sets collected at different times. The EM sensor is physically isolated from a surrounding environment. The surveys are combined to produce a time lapse earth model of the regions of interest.

Claims

1. An onshore electromagnetic (EM) reservoir monitoring system that comprises:

a light source that produces an interrogation light beam;

an array of EM sensors positioned above ground or buried underground within an onshore production field and above one or more regions of interest within a subterranean formation, the EM sensors coupled to each other and the light source with at least one optical fiber, wherein at least one of the EM sensors modulates the interrogation light beam in response to an EM signal induced into the subterranean formation by an EM source;

a processor that couples to and controls the light source, and further couples to and processes the modulated light received from the array via the at least one optical fiber, wherein said EM sensors and said processor collect EM data to produce two or more EM surveys, each EM survey based on data sets collected at different times;

wherein each EM sensor is physically isolated from a surrounding environment, the EM sensor comprising two cylindrical electrodes arranged provide sensing surfaces to receive the EM signal, a cylindrical encapsulation layer arranged over the cylindrical electrodes to isolate the cylindrical electrodes from the surrounding environment, an optical transducer arranged within the cylindrical electrodes, and the optical fiber arranged within the optical transducer, wherein the optical transducer is arranged to modulate the interrogation light beam in response to the EM signal induced into the subterranean formation by the EM source; and

wherein the two or more surveys are combined to produce a time-lapse earth model of the one or more regions of interest.

2. The system of claim 1, wherein the data sets corresponding to at least two of the two or more EM surveys are collected at times separated by at least one month.

3. The system of claim 1, wherein the cylindrical electrodes are encapsulated in fiberglass to avoid direct contact with the surrounding environment and are each capacitively coupled to the ground of the onshore production field.

4. The system of claim 1, wherein the EM source comprises a controlled EM source coupled to and controlled by the processor or comprises a natural EM source.

5. The system of claim 1, wherein the collected EM data is sampled continuously.

6. The system of claim 1, wherein the at least one EM sensor comprises a transducer selected from the group consisting of an optical cavity transducer, a variable optical path length transducer and a microbender transducer.

7. The system of claim 1, wherein the collected EM data is combined with other geophysical data or other production data to improve resolution of the time lapse earth model of the one or more regions of interest.

8. The system of claim 1, wherein the at least one optical fiber is part of a distributed temperature sensor system (DTSS) and wherein temperature data from the DTSS is used to calibrate the collected EM data.

9. The system of claim 1, wherein the at least one optical fiber further couples to a seismic sensing system and wherein the processor combines seismic data from the seismic sensing system with the collected EM data to improve resolution of the earth model of the one or more regions of interest.

10. An onshore electromagnetic (EM) reservoir monitoring method that comprises:

causing a light source to direct a beam of light through at least one optical fiber to an array of EM sensors placed above ground or buried underground within an onshore production field and above one or more regions of interest within a subterranean formation;

receiving a modulated version of the beam of light, at least one of the one or more EM sensors modulating the beam of light in response to an EM signal induced within the subterranean formation by an EM source, each EM sensor being physically isolated from a surrounding environment, the EM sensor comprising two cylindrical electrodes arranged provide sensing surfaces to receive the EM signal, a cylindrical encapsulation layer arranged over the cylindrical electrodes to isolate the cylindrical electrodes from the surrounding environment, an optical transducer arranged within the cylindrical electrodes, and the optical fiber arranged within the optical transducer, wherein the optical transducer is arranged to modulate the beam of light in response to the EM signal induced into the surrounding environment by the EM source;

collecting EM data based on the received modulated light beam and producing two or more EM surveys, each EM survey based on data sets collected at different time;

combining the two or more surveys and producing a time-lapse earth model of the one or more regions of interest; and

executing simulations using the time-lapse earth model to predict reservoir behavior and displaying simulation results.

11. The method of claim 10, wherein the collecting of EM data for data sets corresponding to at least two of the two or more EM surveys each occurs at times separated by at least one month.

12. The method of claim 10, further comprising using the cylindrical electrodes to avoid direct contact with the surrounding environment, said cylindrical electrodes being capacitively coupled to the ground of the onshore production field, wherein the cylindrical electrodes are encapsulated in fiberglass.

13. The method of claim 10, wherein the EM source comprises a controlled EM source or a natural EM source.

14. The method of claim 10, further comprising collecting the EM data continuously.

15. The method of claim 10, wherein at least one of the one or more EM sensors comprises a transducer selected from the group consisting of an optical cavity transducer, a variable optical path length transducer and a microbender transducer.

16. The method of claim 10, further comprising combining the collected EM data with other geophysical data or other production data to improve resolution of the time lapse earth model of the one or more regions of interest.

17. The method of claim 10, wherein the at least one optical fiber is part of a distributed temperature sensor system (DTSS) and the method further comprising calibrating the collected EM data with temperature data from the DTSS.

18. The method of claim 10, wherein the at least one optical fiber further couples to a seismic sensing system and the method further comprises combining seismic data from the seismic sensing system with the collected EM data to improve resolution of one or more reservoir models.