Apparatus and method for detecting fracture geometry using acoustic telemetry

• US 9,557,434 B2
• Filed: 12/18/2013
• Issued: 01/31/2017
• Est. Priority Date: 12/19/2012
• Status: Active Grant

• Current Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Original Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Inventors: Keller, Stuart R., Morrow, Timothy I., Deffenbaugh, Max, Disko, Mark M., Stiles, David A.
• Primary Examiner(s): NWUGO, OJIAKO K
• Application Number:
  US14/434,730
• Publication Number:
  US 20150285937A1
• Time in Patent Office: 1,140 Days
• Field of Search: 340/854.4, 340/854.8, 367/82
• US Class Current: 1/1
• CPC Class Codes: E21B 43/26 by forming crevices or fractures
• CPC Class Codes: E21B 47/13 by electromagnetic energy, e.g. radio frequency
• CPC Class Codes: E21B 47/14 using acoustic waves
• CPC Class Codes: E21B 47/16 through the drill string or casing , e.g. by torsional acoustic waves
• CPC Class Codes: E21B 49/00 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 Class Codes: G01V 1/40 specially adapted for well-logging
• CPC Class Codes: G01V 1/52 Structural details
• CPC Class Codes: G01V 11/002 Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant means for transmitting well survey signals E21B47/12; signal transmission systems in general G08C; transmission in general H04B
• CPC Class Codes: G01V 2210/123 Passive source, e.g. microseismics
• CPC Class Codes: G01V 2210/1234 Hydrocarbon reservoir, e.g. spontaneous or induced fracturing
• CPC Class Codes: G01V 2210/1429 Subsurface, e.g. in borehole or below weathering layer or mud line
• CPC Class Codes: G01V 2210/646 Fractures

Abstract

An electro-acoustic system for downhole telemetry employs a series of communications nodes spaced along a string of casing within a wellbore. The nodes allow wireless communication between transceivers residing within the communications nodes and a receiver at the surface. The transceivers provide node-to-node communication of data indicating elastic waves generated as a result of the formation of subsurface fractures. The data is processed which generates a map of fracture geometry. A method of evaluating fracture geometry in a subsurface formation uses a plurality of data transmission nodes situated along the casing string which send signals to a receiver at the surface. The signals are analyzed which generates a subsurface map.

Claims

1. An electro-acoustic telemetry system for evaluating fracture geometry in a subsurface formation, comprising:

a casing string disposed in a wellbore, the casing string being comprised of pipe joints connected end-to-end;

at least two sensors disposed along the wellbore and configured to detect elastic waves within the subsurface formation;

a series of communications nodes placed along the wellbore, the communications nodes being configured to relay acoustic signals indicative of elastic waves caused by movement of rock within the subsurface formation as detected by the sensors;

a receiver at the surface configured to receive signals from an uppermost of the communications nodes;

wherein each of the communications nodes comprises;

a sealed housing;

an electro-acoustic transducer and associated transceiver also residing within the housing designed to relay acoustic signals from node-to-node up the wellbore and to the receiver during a wellbore operation; and

an independent power source residing within the housing providing power to the transceiver.

2. The electro-acoustic telemetry system of claim 1, wherein the series of communications nodes comprises:

two or more sensor communications node connected to an outer surface of the casing string, the sensor communications nodes configured to receive signals from respective sensors;

a topside communications node placed proximate a surface of the wellbore; and

a plurality of intermediate communications nodes spaced along the wellbore between the sensor communications nodes and the topside communications node.

3. The electro-acoustic telemetry system of claim 2, wherein:

each of the at least two sensors resides within the housing of a selected sensor communications node;

the electro-acoustic transducers within the selected subsurface communications nodes convert signals from the sensors into acoustic signals for the associated transceivers; and

each of the sensor communications nodes is configured to generate a signal from the transceiver representing a packet of information that comprises an identifier for the sensor communications node that originally transmitted the signal, and an acoustic waveform representing the elastic waves detected by its corresponding sensor.

4. The electro-acoustic telemetry system of claim 3, wherein a frequency band for the acoustic waveform transmission by the transceivers is about 25 kHz wide.

5. The electro-acoustic system of claim 3, wherein a frequency band for the acoustic wave transmission by the transceivers operates from about 100 kHz to 125 kHz.

6. The electro-acoustic telemetry system of claim 3, wherein the acoustic waveforms provide data that is modulated by (i) a multiple frequency shift keying method, (ii) a frequency shift keying method, (iii) a multi-frequency signaling method, (iv) a phase shift keying method, (v) a pulse position modulation method, or (vi) an on-off keying method.

7. The electro-acoustic telemetry system of claim 2, wherein the intermediate communications nodes are spaced apart such that each joint of pipe supports at least one intermediate communications node.

8. The electro-acoustic telemetry system of claim 2, wherein the intermediate communications nodes are spaced at about 10 to 100 foot (3.0 to 30.5 meter) intervals.

9. The electro-acoustic telemetry system of claim 2, wherein the sensor communications nodes and the intermediate communications nodes transmit data in acoustic form at a rate exceeding about 50 bps.

10. The electro-acoustic telemetry system of claim 2, wherein each of the at least two sensors is a microphone or a geophone.

11. The electro-acoustic telemetry system of claim 2, wherein each of the electro-acoustic transceivers in the intermediate communications nodes is designed to receive acoustic waves at a first frequency, and then transmit the acoustic waves at a second different frequency up the wellbore to a next subsurface communications node.

12. The electro-acoustic telemetry system of claim 11, wherein each intermediate communications node listens for the acoustic waves generated at the first frequency for a longer time than the time for which the acoustic waves were generated at the second frequency by a previous intermediate communications node.

13. The electro-acoustic telemetry system of claim 2, wherein:

a well head is placed above the wellbore; and

the topside communications node is placed (i) on an outer surface of the well head or (ii) on an outer surface of an uppermost joint of the casing string.

14. The electro-acoustic telemetry system of claim 13, wherein the signal from the topside communications node to the receiver is transmitted via a Class I, Division I conduit or a wireless transmission.

15. The electro-acoustic telemetry system of claim 2, wherein the intermediate communications nodes are attached to the outer wall of the casing string by (i) an adhesive material, (ii) welding, or (iii) one or more mechanical fasteners.

16. The electro-acoustic telemetry system of claim 2, wherein:

each of the intermediate communications nodes is attached to the casing string by one or more clamps; and

each of the one or more clamps comprises;

a first arcuate section;

a second arcuate section;

a hinge for pivotally connecting the first and second arcuate sections; and

a fastening mechanism for securing the first and second arcuate sections around an outer surface of the casing string.

17. The electro-acoustic telemetry system of claim 1, further comprising:

a processor programmed to correlate signals from the elastic wave sensors with the respective subsurface communications nodes, identify a source location of the elastic waves within the subsurface formation, and then generate a subsurface map reflecting geographic origins of the elastic waves.

18. The electro-acoustic telemetry system of claim 16, wherein:

selected communications nodes further comprise a temperature sensor, with those selected communications nodes being designed to generate a signal that corresponds to temperature readings taken by the respective temperature sensors; and

the transceivers transmit acoustic signals up the wellbore representative of the temperature readings, node-to-node, as part of the packets of information.

19. The electro-acoustic telemetry system of claim 17, wherein the processor is further programmed to identify temperature values generated by the selected subsurface communications node and compare those temperature values to a baseline temperature value.

20. A method of evaluating fracture geometry in a subsurface formation, comprising:

running joints of casing into the wellbore, the joints of casing being connected by threaded couplings to form a casing string;

attaching a series of communications nodes to the joints of casing according to a pre-designated spacing, wherein adjacent communications nodes are configured to communicate by acoustic signals transmitted through the joints of casing, and wherein each of the communications nodes comprises;

a sealed housing;

an electro-acoustic transducer and associated transceiver residing within the housing configured to relay signals, with each signal representing a packet of information that comprises (i) an identifier for the subsurface communications node originally transmitting the signal, and (ii) an acoustic waveform indicative of elastic waves caused by movement of rock within the subsurface formation during a wellbore operation; and

an independent power source also residing within the housing for providing power to the transceiver;

sending signals from the communications nodes to a receiver at a surface via the series of communications nodes;

processing the signals to determine the geographical origin of the elastic waves; and

generating a map of subsurface fractures from the processed signals.

21. The method of claim 20, wherein the surface is an earth surface, or a drilling or production platform over a water surface.

22. The method of claim 20, wherein the housing for each of the communications nodes is fabricated from a steel material, with the steel material of the housing having a resonant frequency within a width of the resonant frequency of the acoustic waveforms transmitted through the joints of casing.

23. The method of claim 20, wherein:

the movement of rock is detected by sensors residing within the subsurface communications nodes originally transmitting the signals.

24. The method of claim 20, wherein each of the at least two sensors is a microphone or a geophone.

25. The method of claim 24, further comprising:

injecting a fluid through perforations in the casing string under pressure in order to form subsurface fractures; and

using the sensors, detecting elastic waves generated as a result of injecting the fluid.

26. The method of claim 20, wherein the series of communications nodes comprises:

two or more sensor communications nodes connected to an outer surface of the casing string and configured to receive signals from respective sensors along the wellbore;

a topside communications node placed proximate a surface of the wellbore; and

a plurality of intermediate communications nodes spaced along the wellbore between the sensor communications nodes and the topside communications node.

27. The method of claim 26, wherein:

the electro-acoustic transducers within the sensor communications nodes convert signals from the sensors into acoustic signals for the associated transceivers;

each of the sensor communications nodes generates a signal from the transceiver representing a packet of information that comprises an identifier for the sensor communications node that originally transmitted the signal, and an acoustic waveform representing the waves detected by its corresponding sensor; and

the topside communications node transmits the signals from an uppermost intermediate communications node to the receiver.

28. The method of claim 27, wherein a frequency band for the acoustic waveform transmission by the transceivers is about 25 kHz wide.

29. The method of claim 27, wherein a frequency band for the acoustic wave transmission by the transceivers operates from about 100 kHz to 125 kHz.

30. The method of claim 27, wherein the acoustic waveforms provide data that is modulated by (i) a multiple frequency shift keying method, (ii) a frequency shift keying method, (iii) a multi-frequency signaling method, (iv) a phase shift keying method, (v) a pulse position modulation method, or (vi) an on-off keying method.

31. The method of claim 27, wherein each of the at least two sensors resides within the housing of a selected sensor communications node.

32. The method of claim 27, wherein the intermediate communications nodes are spaced apart such that each joint of pipe supports at least one intermediate communications node.

33. The method of claim 27, wherein the intermediate communications nodes are spaced at about 20 to 40 foot (6.1 to 12.2 meter) intervals.

34. The method of claim 27, wherein the sensor communications nodes and the intermediate communications nodes transmit data in acoustic form at a rate exceeding about 50 bps.

35. The method of claim 27, wherein each of the intermediate and each of the subsurface communications nodes is attached to a wall surface of a joint of casing by (i) an adhesive material, (ii) welding, or (iii) one or more mechanical fasteners.

36. The method of claim 27, wherein:

each of the each of the intermediate and each of the subsurface communications nodes is attached to a joint of casing by one or more clamps; and

the step of attaching the communications nodes to the joints of casing comprises clamping the communications nodes to an outer surface of the joints of casing.

37. The method of claim 36, wherein each of the one or more clamps comprises:

a first arcuate section;

a second arcuate section;

a hinge for pivotally connecting the first and second arcuate sections; and

a fastening mechanism for securing the first and second arcuate sections around an outer surface of the casing string.

38. The method of claim 36, wherein:

the housing of each of the intermediate and each of the sensor communications nodes comprises a first end and a second opposite end; and

each of the one or more clamps comprises a first clamp secured at the first end of the housing, and a second clamp secured at the second end of the housing.

39. The method of claim 27, wherein analyzing the signals to determine the geographical origin of the elastic waves comprises:

receiving elastic waves generated by micro-seismic events at a plurality of sensors along the wellbore;

correlating individual micro-seismic events in two or more of the sensors; and

triangulating the individual micro-seismic events.

40. The method of claim 39, wherein triangulating is based on strength of the signals, time of receipt of the signals, or both.

41. The method of claim 39, wherein:

at least two of the subsurface communications nodes further comprises a temperature sensor, and generate a signal that corresponds to temperature readings taken by the temperature sensor;

the transceivers in the sensor communications nodes transmit acoustic signals up the wellbore representative of the temperature readings, node-to-node; and

wherein analyzing the signals to determine the geographical origin of the elastic waves further comprises determining whether any changes in temperature readings are indicative of the presence of near-wellbore subsurface fractures.