WO2015099641A1 - Downhole signal repeater - Google Patents

Downhole signal repeater Download PDF

Info

Publication number
WO2015099641A1
WO2015099641A1 PCT/US2013/077382 US2013077382W WO2015099641A1 WO 2015099641 A1 WO2015099641 A1 WO 2015099641A1 US 2013077382 W US2013077382 W US 2013077382W WO 2015099641 A1 WO2015099641 A1 WO 2015099641A1
Authority
WO
WIPO (PCT)
Prior art keywords
repeater
sensor
signal
well
sound
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2013/077382
Other languages
French (fr)
Inventor
William Mark Richards
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to US14/413,906 priority Critical patent/US9650889B2/en
Priority to GB1605452.0A priority patent/GB2537494B/en
Priority to PCT/US2013/077382 priority patent/WO2015099641A1/en
Publication of WO2015099641A1 publication Critical patent/WO2015099641A1/en
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E21B47/07—Temperature

Definitions

  • This disclosure relates to deep water and other oil wells and the communication of information from the wells to the surface.
  • Drilling, preparing for extraction and extraction of hydrocarbons from wells require awareness of location, condition or other information from the bottom and other intermediate points in the well. Some of such data may be provided by listening to sound traveling to the surface, but sounds from deep wells often do not reach the surface or are so attenuated as to be inaudible at the surface. Other signals or forms of data transfer likewise may not reach the surface.
  • Figure 1 is a schematized diagram of a repeater for use in a well.
  • Figure 2 is a schematized diagram of a repeater for use in a well that includes an array of transmission units.
  • Figure 3 is a side view of a signal receiving apparatus above a rig floor.
  • Figure 4 is an enlarged, schematized view of the signal receiving apparatus shown in Figure 3.
  • a relatively inexpensive repeater may be positioned in a well to detect events or conditions deeper in the well such as sounds, vibrations, pressure conditions, or changes or other events or conditions perceptible with a sensor. The repeater then transmits a signal or signals to the rig floor or another desired uphole location.
  • Figure 1 depicts a repeater 10 having a sensor 12 that generates a signal that actuates a pushing device such as an actuator, solenoid or piston 14 that pushes a mass such as a shuttle or counterweight 16.
  • the counterweight 16 is driven into a stop 22 coupled to a mandrel 24 or other well structure with sufficient force to cause a discernible event at the well surface, such as a "bobble" of a weight indicator gauge 28.
  • Actuation of the piston 14 may involve, in addition to the sensor 12, a power source such as a battery 18 and optional computational circuitry 20 for outputting a signal that will actuate the piston 14 or another driver to cause the counterweight 16 to impact stop 22 with sufficient force to be detected uphole.
  • a second device for moving the counterweight 16 such as a solenoid or reset piston 26 may be utilized to automatically return the counterweight 16 to its rest position to prepare it for repetition of another signal.
  • the sensor 12 may be a microphone or other sound sensor if the signal to be repeated is a sound.
  • Other sensors such as strain gauges, pressure gauges, temperature gauges, hydrophones, accelerometers or other sensors that detect events or conditions may also be usable with the other components described here, depending on the signal desired to be communicated through the well.
  • the repeater 10 may be controlled by an operator on the rig floor.
  • control signal may be an acoustic signal, a pressure signal (a pulse or series of sustained pressure holds), a series of tension and compression read by stain gauges in the mandrel, up and down motion read by accelerometers, or a dropped ball from surface with an RFID tag or magnet.
  • Such multi-track repeater 40 uses a sensor or sensors 42 coupled to power and control circuitry 44 that triggers pistons 46 that strike or drive counterweights 48 that travel in tracks 50 to strike a stop 52 or multiple stops (not shown).
  • a downhole sound or other event or condition detected by sensor 42 is received by the powered control circuit 44 that actuates multiple pistons 46 to drive counterweights 48 in tracks 50 simultaneously or in a pattern.
  • a pattern may be, for example, two strikes closely spaced in time followed by a third strike after a time interval greater than the interval between the first two impacts.
  • firing patterns of pistons 44 driving counterweights 48 can be used, for instance, (1) in order to communicate more about the received sound (or other detected event or condition) than just its receipt, or (2) in order to send a signal uphole that can be more easily differentiated from "noise.”
  • the signal transmitted to the surface or other area above the rig floor may be heard by workers or may be received on existing equipment such by causing a "bobble" on a weight indicator 28 ( Figure 1).
  • a signal may be received by a dedicated receiver, an exemplary one of which is depicted in Figures 3 and 4.
  • Such a receiver 60 may be located at the top of a work string 62. As shown in
  • the receiver 60 may include a power source such as a battery 64, a sensor 66 and a light, flag or sound production device 68 that is perceptible by a rig operator or detectable by another means at or near the rig floor 29.
  • a power source such as a battery 64, a sensor 65 and computational circuitry 67, including a data link port or Wi-Fi capability 69 so that data can be monitored contemporaneously or stored for later analysis or both.
  • a repeater 10 ( Figure 1) or 40 ( Figure 2) is positioned generally vertically with the sensor 12 at the bottom (the downhole end of the repeater 10 or 40), gravity alone may return the counterweight 16 or counterweights 48 to their rest positions.
  • the repeater 10 or 40 may be oriented relatively horizontally, or there may be other structures or conditions, so that gravity may not return the counterweights 16 or 48 to their rest positions.
  • repeater 10 or 40 may be oriented so that the counterweights 16 or 48 travel uphole when actuated, in some instances it may be desirable for the counterweights 16 or 48 to move downhole when actuated because, for instance, it is desired that the weight indicator 28 ( Figure 1) register a greater weight when the repeater 10 is actuated and the counterweight 16 strikes the stop 22.
  • piston 14 Figure 1
  • pistons 46 Figure 2
  • actuation of piston 14 or 46 travel alone or actuation of the piston and direct impact of piston 14 with stop 22 or of pistons 46 with stop 52 may cause an adequate "bobble" or other event at the rig floor 29 or at an uphole repeater to achieve the desired repetition of a downhole signal or event.
  • counterweights 16 and 48 may be used to cause counterweights 16 and 48 to impact their respective stops 22 and 52, such as, but not limited to, compressed or pressurized fluid, electromagnetic field propulsion, and gravitational attraction.
  • a downhole repeater, method or system receives, amplifies, repeats or transmits according to one or more of the following examples.
  • Example #1 A repeater or downhole system for use in a well to detect a sound, condition or signal in the well and communicate that detection uphole can include a sensor, actuator and control circuitry.
  • the sensor can detect an in-well sound, condition or signal.
  • the actuator can generate a perceptible signal or physical change.
  • the control circuitry for detecting the in-well sound, condition or signal can be coupled to the sensor and can actuate the actuator in response to the in- well sound, condition or signal.
  • Example #2 The repeater or system of Example #1 may feature a stop and a counterweight to be driven by the actuator against the stop from a rest position.
  • Example #3 The repeater or system of Examples #1-2 may feature an actuator that includes a drive piston.
  • Example #4 The repeater or system of Examples #1-2 may feature a reset piston for returning the counterweight to the rest position after it has been driven by the drive piston.
  • Example #5 The repeater or system of Examples #1-4 may feature control circuitry that turns the repeater or system on and off, or that otherwise controls the repeater or system, in response to control signals.
  • Example #6 The repeaters or systems of Examples #1-5 may feature a sensor that is a microphone.
  • Example #7 The repeaters or systems of Examples #1-6 may feature sensor that is capable of sensing pressure.
  • Example #8 The repeaters or systems of Examples #1-7 may feature a sensor that is or includes an accelerometer.
  • Example #9 The repeaters or systems of Examples #1-8 may feature a sensor that is or includes a strain gauge.
  • Example #10 The repeaters or systems of Examples #1-9 may feature a sensor that is or includes a hydrophone.
  • a repeater for use in a well to detect a sound, condition or signal in the well and communicate that detection uphole may include a sensor, multiple actuators and control circuitry.
  • the sensor may detect the in-well sound, condition or signal.
  • the actuators can generate a perceptible signal or physical change.
  • the control circuitry can be coupled to the sensor and the actuators and can actuate the actuators when the in-well sound, condition or signal is received by the sensor.
  • Example #12 The repeater of Example #11 can actuate the actuators so that each of the actuators drives one counterweight against one stop.
  • the control circuitry can control the time intervals between the activation of the actuators according to a predetermined pattern.
  • Example #13 The repeater of Examples #11 and 12 may feature one or more actuators that are drive pistons.
  • Example #14 The repeater of Examples #11-13 may feature for each counterweight a reset piston for returning the counterweight to a rest position after it has been driven by a drive piston.
  • Example #15 The repeater of Examples #1-14 may feature a power source for the sensor, circuitry and actuators.
  • Example #16 The repeaters of Examples #1-4 and 11-14 may also feature control circuitry for controlling operation of the repeater in response to control signals received by the sensor.
  • Example #17 The repeaters of Examples #1-16 may feature a sensor that is one or more of a microphone, pressure sensor, accelerometer, strain gauge or hydrophone.
  • Example #18 The repeaters or systems of Examples #1-17 may feature a receiver for use proximate a rig floor, and the receiver may include a receiver sensor, a power source, and on output device.
  • Example #19 The repeater or systems of Example #18 may feature a receiver sensor that is one or more of a microphone, pressure sensor, accelerometer, strain gauge or hydrophone.
  • Example # 20 The repeaters or systems of Example #18 may feature an output device generates a signal that is visible or audible.
  • a visible signal may be produced, without limitation, by a meter, a light-emitting component such as a laser, a LED, or an incandescent, florescent or other lamp.
  • a sound-emitting component such as a laser, a LED, or an incandescent, florescent or other lamp.
  • Such an audible signal may be produced by a bell, a buzzer, a speaker or any other device capable of generating sound.
  • Example #21 A method of receiving at a rig floor information from deep within a well may utilize a repeater and well equipment.
  • the repeater may be positioned in the well intermediate the rig floor and a location deeper in the well about which information is desired.
  • the well equipment may be manipulated in the well to cause a first signal to emanate from the location deeper in the well about which information is desired.
  • the repeater then may receive the first signal and transmit a second signal to the rig floor.

Landscapes

  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geophysics (AREA)
  • Acoustics & Sound (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Measurement Of Mechanical Vibrations Or Ultrasonic Waves (AREA)
  • Radio Relay Systems (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)

Abstract

A repeater for use downhole in an oil or other well for detecting a sound or other signal that originates further downhole and generating a signal or indication perceptible uphole or at or above the rig floor. The signal may be a change in the weight of the rig measured at the rig floor caused by driving a counterweight against a stop at the repeater.

Description

DOWNHOLE SIGNAL REPEATER
TECHNICAL FIELD
[0001] This disclosure relates to deep water and other oil wells and the communication of information from the wells to the surface.
BACKGROUND
[0002] Drilling, preparing for extraction and extraction of hydrocarbons from wells require awareness of location, condition or other information from the bottom and other intermediate points in the well. Some of such data may be provided by listening to sound traveling to the surface, but sounds from deep wells often do not reach the surface or are so attenuated as to be inaudible at the surface. Other signals or forms of data transfer likewise may not reach the surface.
[0003] Signals can be transmitted from a point in a well to the surface or another location on electrical or optical fiber cable, but in some situations such alternatives are prohibitively expensive or otherwise impractical or impossible.
BRIEF DESCRIPTION OF THE DRAWINGS
[0004] Illustrative embodiments of the present disclosure are described in detail below with reference to the following drawing figures:
[0005] Figure 1 is a schematized diagram of a repeater for use in a well.
[0006] Figure 2 is a schematized diagram of a repeater for use in a well that includes an array of transmission units.
[0007] Figure 3 is a side view of a signal receiving apparatus above a rig floor. [0008] Figure 4 is an enlarged, schematized view of the signal receiving apparatus shown in Figure 3.
DETAILED DESCRIPTION
[0009] The subject matter of embodiments of this disclosure is described here with specificity to meet statutory requirements, but this description is not necessarily intended to limit the scope of the claims. The claimed subject matter may be embodied in other ways, may include different elements or steps, and may be used in conjunction with other existing or future technologies. This description should not be interpreted as implying any particular order or arrangement among or between various steps or elements except when the order of individual steps or arrangement of elements is explicitly described.
[0010] A relatively inexpensive repeater may be positioned in a well to detect events or conditions deeper in the well such as sounds, vibrations, pressure conditions, or changes or other events or conditions perceptible with a sensor. The repeater then transmits a signal or signals to the rig floor or another desired uphole location.
[0011] Figure 1 depicts a repeater 10 having a sensor 12 that generates a signal that actuates a pushing device such as an actuator, solenoid or piston 14 that pushes a mass such as a shuttle or counterweight 16. The counterweight 16 is driven into a stop 22 coupled to a mandrel 24 or other well structure with sufficient force to cause a discernible event at the well surface, such as a "bobble" of a weight indicator gauge 28.
[0012] Actuation of the piston 14 may involve, in addition to the sensor 12, a power source such as a battery 18 and optional computational circuitry 20 for outputting a signal that will actuate the piston 14 or another driver to cause the counterweight 16 to impact stop 22 with sufficient force to be detected uphole. A second device for moving the counterweight 16 such as a solenoid or reset piston 26 may be utilized to automatically return the counterweight 16 to its rest position to prepare it for repetition of another signal.
[0013] The sensor 12 may be a microphone or other sound sensor if the signal to be repeated is a sound. Other sensors such as strain gauges, pressure gauges, temperature gauges, hydrophones, accelerometers or other sensors that detect events or conditions may also be usable with the other components described here, depending on the signal desired to be communicated through the well.
[0014] The repeater 10 may be controlled by an operator on the rig floor. The sensor
12 may detect a control signal from the surface to turn the repeater 10 on, turn the repeater 10 off, change the strength of the return signal or otherwise control the repeater 10. For instance, the operator may send a control signal down the tubing to the sensor 12. The operator may also or alternatively send a control signal down the annulus to the sensor 12. Among other alternatives, the control signal may be an acoustic signal, a pressure signal (a pulse or series of sustained pressure holds), a series of tension and compression read by stain gauges in the mandrel, up and down motion read by accelerometers, or a dropped ball from surface with an RFID tag or magnet.
[0015] The simplest operation of the repeater 10 of Figure 1 involves receipt of a sound or other signal that is treated as a single event or pulse and actuation once of the piston 14 to drive the counterweight 16 against the stop 22.
[0016] Rather than a single large counterweight 16, multiple weights in tracks can be used to create a distinctive pattern of signals that may be more easily recognized at the surface because of the pattern. Figure 2 depicts such an embodiment in schematized form.
[0017] Such multi-track repeater 40 uses a sensor or sensors 42 coupled to power and control circuitry 44 that triggers pistons 46 that strike or drive counterweights 48 that travel in tracks 50 to strike a stop 52 or multiple stops (not shown). [0018] In this embodiment 40, a downhole sound or other event or condition detected by sensor 42 is received by the powered control circuit 44 that actuates multiple pistons 46 to drive counterweights 48 in tracks 50 simultaneously or in a pattern. Such a pattern may be, for example, two strikes closely spaced in time followed by a third strike after a time interval greater than the interval between the first two impacts. Numerous other "firing patterns" of pistons 44 driving counterweights 48 can be used, for instance, (1) in order to communicate more about the received sound (or other detected event or condition) than just its receipt, or (2) in order to send a signal uphole that can be more easily differentiated from "noise."
[0019] The signal transmitted to the surface or other area above the rig floor (not shown in Figures 1 and 2) may be heard by workers or may be received on existing equipment such by causing a "bobble" on a weight indicator 28 (Figure 1). Alternatively, such a signal may be received by a dedicated receiver, an exemplary one of which is depicted in Figures 3 and 4.
[0020] Such a receiver 60 may be located at the top of a work string 62. As shown in
Figure 3, the receiver 60 may include a power source such as a battery 64, a sensor 66 and a light, flag or sound production device 68 that is perceptible by a rig operator or detectable by another means at or near the rig floor 29. Alternatively, or additionally, receiver 60 may include a power source such as a battery 64, a sensor 65 and computational circuitry 67, including a data link port or Wi-Fi capability 69 so that data can be monitored contemporaneously or stored for later analysis or both.
[0021] In situations where the depth of the sound or other signal source means that one repeater 10 or 40 cannot or may not produce a sufficiently strong repeated signal for the repeated signal to be reliably detected at or near the rig floor 29, one or more additional repeaters may be utilized at intervals within the well over which repeated signals can be reliably transmitted. [0022] Different arrangements of the components depicted in the drawings or described here, as well as components and steps not shown or described are possible. Similarly, some features and subcombinations are useful and may be employed without reference to other features and subcombinations. Embodiments of the disclosure have been described for illustrative and not restrictive purposes, and alternative embodiments will become apparent to readers of this patent. Accordingly, the present disclosure is not limited to the embodiments described here or depicted in the drawings, and various embodiments and modifications can be made without departing from the scope of the claims below.
[0023] For instance, if a repeater 10 (Figure 1) or 40 (Figure 2) is positioned generally vertically with the sensor 12 at the bottom (the downhole end of the repeater 10 or 40), gravity alone may return the counterweight 16 or counterweights 48 to their rest positions. However, the repeater 10 or 40 may be oriented relatively horizontally, or there may be other structures or conditions, so that gravity may not return the counterweights 16 or 48 to their rest positions. Moreover, while the repeater 10 or 40 may be oriented so that the counterweights 16 or 48 travel uphole when actuated, in some instances it may be desirable for the counterweights 16 or 48 to move downhole when actuated because, for instance, it is desired that the weight indicator 28 (Figure 1) register a greater weight when the repeater 10 is actuated and the counterweight 16 strikes the stop 22.
[0024] Other means for "resetting" the positions of counterweights 16 or 48 are also possible, including one or more springs such as a helical spring (not shown) that permits counterweight 16 or counterweights 48 travel until impact with the stop 22 or stop 52 but that then pulls the counterweights back to their rest positions.
[0025] Other configurations of the piston 14 and counterweight 16 are also possible.
For instance, it may be possible in some circumstances to use a piston 14 (Figure 1) or pistons 46 (Figure 2) with sufficient mass and stroke that separate counterweights are not needed. In such a configuration, actuation of piston 14 or 46 travel alone or actuation of the piston and direct impact of piston 14 with stop 22 or of pistons 46 with stop 52 may cause an adequate "bobble" or other event at the rig floor 29 or at an uphole repeater to achieve the desired repetition of a downhole signal or event.
[0026] Similarly, different means may be used to cause counterweights 16 and 48 to impact their respective stops 22 and 52, such as, but not limited to, compressed or pressurized fluid, electromagnetic field propulsion, and gravitational attraction.
[0027] In some aspects, a downhole repeater, method or system receives, amplifies, repeats or transmits according to one or more of the following examples.
[0028] Example #1 : A repeater or downhole system for use in a well to detect a sound, condition or signal in the well and communicate that detection uphole can include a sensor, actuator and control circuitry. The sensor can detect an in-well sound, condition or signal. The actuator can generate a perceptible signal or physical change. The control circuitry for detecting the in-well sound, condition or signal can be coupled to the sensor and can actuate the actuator in response to the in- well sound, condition or signal.
[0029] Example #2: The repeater or system of Example #1 may feature a stop and a counterweight to be driven by the actuator against the stop from a rest position.
[0030] Example #3: The repeater or system of Examples #1-2 may feature an actuator that includes a drive piston.
[0031] Example #4: The repeater or system of Examples #1-2 may feature a reset piston for returning the counterweight to the rest position after it has been driven by the drive piston.
[0032] Example #5: The repeater or system of Examples #1-4 may feature control circuitry that turns the repeater or system on and off, or that otherwise controls the repeater or system, in response to control signals. [0033] Example #6: The repeaters or systems of Examples #1-5 may feature a sensor that is a microphone.
[0034] Example #7: The repeaters or systems of Examples #1-6 may feature sensor that is capable of sensing pressure.
[0035] Example #8: The repeaters or systems of Examples #1-7 may feature a sensor that is or includes an accelerometer.
[0036] Example #9: The repeaters or systems of Examples #1-8 may feature a sensor that is or includes a strain gauge.
[0037] Example #10: The repeaters or systems of Examples #1-9 may feature a sensor that is or includes a hydrophone.
[0038] Example #11 : A repeater for use in a well to detect a sound, condition or signal in the well and communicate that detection uphole may include a sensor, multiple actuators and control circuitry. The sensor may detect the in-well sound, condition or signal. The actuators can generate a perceptible signal or physical change. The control circuitry can be coupled to the sensor and the actuators and can actuate the actuators when the in-well sound, condition or signal is received by the sensor.
[0039] Example #12: The repeater of Example #11 can actuate the actuators so that each of the actuators drives one counterweight against one stop. The control circuitry can control the time intervals between the activation of the actuators according to a predetermined pattern.
[0040] Example #13. The repeater of Examples #11 and 12 may feature one or more actuators that are drive pistons.
[0041] Example #14: The repeater of Examples #11-13 may feature for each counterweight a reset piston for returning the counterweight to a rest position after it has been driven by a drive piston. [0042] Example #15: The repeater of Examples #1-14 may feature a power source for the sensor, circuitry and actuators.
[0043] Example #16: The repeaters of Examples #1-4 and 11-14 may also feature control circuitry for controlling operation of the repeater in response to control signals received by the sensor.
[0044] Example #17: The repeaters of Examples #1-16 may feature a sensor that is one or more of a microphone, pressure sensor, accelerometer, strain gauge or hydrophone.
[0045] Example #18: The repeaters or systems of Examples #1-17 may feature a receiver for use proximate a rig floor, and the receiver may include a receiver sensor, a power source, and on output device.
[0046] Example #19: The repeater or systems of Example #18 may feature a receiver sensor that is one or more of a microphone, pressure sensor, accelerometer, strain gauge or hydrophone.
[0047] Example # 20: The repeaters or systems of Example #18 may feature an output device generates a signal that is visible or audible. Such a visible signal may be produced, without limitation, by a meter, a light-emitting component such as a laser, a LED, or an incandescent, florescent or other lamp. Such an audible signal may be produced by a bell, a buzzer, a speaker or any other device capable of generating sound.
[0048] Example #21 : A method of receiving at a rig floor information from deep within a well may utilize a repeater and well equipment. The repeater may be positioned in the well intermediate the rig floor and a location deeper in the well about which information is desired. The well equipment may be manipulated in the well to cause a first signal to emanate from the location deeper in the well about which information is desired. The repeater then may receive the first signal and transmit a second signal to the rig floor.

Claims

CLAIMS That which is claimed is:
1. A repeater for use in a well to detect a sound, condition or signal in the well and communicate that detection uphole, the repeater comprising:
a. a sensor for detecting the in-well sound, condition or signal,
b. an actuator for generating a perceptible signal or physical change, and c. control circuitry coupled to the sensor and the actuator to actuate the actuator when the in- well sound, condition or signal is received by the sensor.
2. The repeater of claim 1, further comprising a stop and a counterweight to be driven by the actuator against the stop from a rest position.
3. The repeater of claim 2, wherein the actuator comprises a drive piston.
4. The repeater of claim 2, further comprising a reset piston for returning the counterweight to the rest position after it has been driven by the drive piston.
5. The repeater of claim 1, wherein the control circuitry turns the repeater on and off in response to control signals.
6. The repeater of claim 1, wherein the sensor comprises a microphone or other sound sensor.
7. The repeater of claim 1 , wherein the sensor comprises a pressure sensor.
8. The repeater of claim 1, wherein the sensor comprises an accelerometer.
9. The repeater of claim 1, wherein the sensor comprises a strain gauge.
10. The repeater of claim 1, wherein the sensor comprises a hydrophone.
11. A repeater for use in a well to detect a sound, condition or signal in the well and communicate that detection uphole, the repeater comprising:
a. a sensor for detecting the in-well sound, condition or signal,
b. a plurality of actuators for generating a perceptible signal or physical change, and
c. control circuitry coupled to the sensor and the actuators to actuate the actuators when an in- well sound, condition or signal is received by the sensor.
12. The repeater of claim 11, wherein each of the plurality of actuators drives one counterweight against one stop and the control circuitry controls the time intervals between the activation of the actuators according to a predetermined pattern.
13. The repeater of claim 12, wherein each actuator comprises a drive piston.
14. The repeater of claim 13, further comprising a reset piston for returning the each of the counterweights to the rest position after it has been driven by each drive piston.
15. The repeater of claim 11, further comprising a power source for the sensor, circuitry and actuators and wherein the control circuitry controls operation of the repeater in response to control signals received by the sensor.
16. The repeater of claim 11, wherein the sensor comprises one of a microphone, pressure sensor, accelerometer, strain gauge or hydrophone.
17. The repeater of claim 1, further comprising a receiver for use proximate a rig floor, the receiver comprising a receiver sensor, a power source, and on output device.
18. The repeater of claim 17, wherein the receiver sensor comprises one of a microphone, pressure sensor, accelerometer, strain gauge or hydrophone.
19. The repeater of claim 17, wherein the output device generates a signal that is visible or audible.
20. A method of receiving at a rig floor information from deep within a well, comprising: a. providing a repeater in the well intermediate the rig floor and a location deeper in the well about which information is desired,
b. manipulating a portion of well equipment in the well to cause a first signal to emanate from the location deeper in the well about which information is desired, and
c. receiving the first signal with the repeater and transmitting a second signal to the rig floor.
PCT/US2013/077382 2013-12-23 2013-12-23 Downhole signal repeater Ceased WO2015099641A1 (en)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US14/413,906 US9650889B2 (en) 2013-12-23 2013-12-23 Downhole signal repeater
GB1605452.0A GB2537494B (en) 2013-12-23 2013-12-23 Downhole signal repeater
PCT/US2013/077382 WO2015099641A1 (en) 2013-12-23 2013-12-23 Downhole signal repeater

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2013/077382 WO2015099641A1 (en) 2013-12-23 2013-12-23 Downhole signal repeater

Publications (1)

Publication Number Publication Date
WO2015099641A1 true WO2015099641A1 (en) 2015-07-02

Family

ID=53479323

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2013/077382 Ceased WO2015099641A1 (en) 2013-12-23 2013-12-23 Downhole signal repeater

Country Status (3)

Country Link
US (1) US9650889B2 (en)
GB (1) GB2537494B (en)
WO (1) WO2015099641A1 (en)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9726004B2 (en) 2013-11-05 2017-08-08 Halliburton Energy Services, Inc. Downhole position sensor
US9784095B2 (en) 2013-12-30 2017-10-10 Halliburton Energy Services, Inc. Position indicator through acoustics
CN107366532A (en) * 2017-07-17 2017-11-21 中国石油大学(华东) Oil-gas pipeline sand production rate monitors experimental provision and monitoring method
US10119390B2 (en) 2014-01-22 2018-11-06 Halliburton Energy Services, Inc. Remote tool position and tool status indication

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6018501A (en) * 1997-12-10 2000-01-25 Halliburton Energy Services, Inc. Subsea repeater and method for use of the same
US6075461A (en) * 1997-12-29 2000-06-13 Halliburton Energy Services, Inc. Disposable electromagnetic signal repeater
US6177882B1 (en) * 1997-12-01 2001-01-23 Halliburton Energy Services, Inc. Electromagnetic-to-acoustic and acoustic-to-electromagnetic repeaters and methods for use of same
US20100013663A1 (en) * 2008-07-16 2010-01-21 Halliburton Energy Services, Inc. Downhole Telemetry System Using an Optically Transmissive Fluid Media and Method for Use of Same
US20100309019A1 (en) * 2004-07-01 2010-12-09 Halliburton Energy Services, Inc. Acoustic telemetry transceiver

Family Cites Families (89)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US618501A (en) * 1899-01-31 Samuel fraser
US5419188A (en) 1991-05-20 1995-05-30 Otis Engineering Corporation Reeled tubing support for downhole equipment module
US5275038A (en) 1991-05-20 1994-01-04 Otis Engineering Corporation Downhole reeled tubing inspection system with fiberoptic cable
US5579842A (en) 1995-03-17 1996-12-03 Baker Hughes Integ. Bottomhole data acquisition system for fracture/packing mechanisms
US5666050A (en) 1995-11-20 1997-09-09 Pes, Inc. Downhole magnetic position sensor
CA2264632C (en) 1997-05-02 2007-11-27 Baker Hughes Incorporated Wellbores utilizing fiber optic-based sensors and operating devices
US6787758B2 (en) 2001-02-06 2004-09-07 Baker Hughes Incorporated Wellbores utilizing fiber optic-based sensors and operating devices
US6281489B1 (en) 1997-05-02 2001-08-28 Baker Hughes Incorporated Monitoring of downhole parameters and tools utilizing fiber optics
US20040043501A1 (en) 1997-05-02 2004-03-04 Baker Hughes Incorporated Monitoring of downhole parameters and chemical injection utilizing fiber optics
US5925879A (en) 1997-05-09 1999-07-20 Cidra Corporation Oil and gas well packer having fiber optic Bragg Grating sensors for downhole insitu inflation monitoring
CA2293686C (en) 1997-06-09 2008-07-29 Baker Hughes Incorporated Control and monitoring system for chemical treatment of an oilfield well
US6769805B2 (en) 1998-08-25 2004-08-03 Sensor Highway Limited Method of using a heater with a fiber optic string in a wellbore
US6429784B1 (en) 1999-02-19 2002-08-06 Dresser Industries, Inc. Casing mounted sensors, actuators and generators
US6343649B1 (en) 1999-09-07 2002-02-05 Halliburton Energy Services, Inc. Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation
US6724319B1 (en) 1999-10-29 2004-04-20 Litton Systems, Inc. Acoustic sensing system for downhole seismic applications utilizing an array of fiber optic sensors
US6728165B1 (en) 1999-10-29 2004-04-27 Litton Systems, Inc. Acoustic sensing system for downhole seismic applications utilizing an array of fiber optic sensors
CA2320453A1 (en) 1999-10-29 2001-04-29 Litton Systems, Inc. Acoustic sensing system for downhole seismic applications utilizing an array of fiber optic sensors
CA2320394A1 (en) 1999-10-29 2001-04-29 Litton Systems, Inc. Acoustic sensing system for downhole seismic applications utilizing an array of fiber optic sensors
US6269198B1 (en) 1999-10-29 2001-07-31 Litton Systems, Inc. Acoustic sensing system for downhole seismic applications utilizing an array of fiber optic sensors
US6288975B1 (en) 1999-10-29 2001-09-11 Litton Systems, Inc. Acoustic sensing system for downhole seismic applications utilizing an array of fiber optic sensors
GB2383633A (en) 2000-06-29 2003-07-02 Paulo S Tubel Method and system for monitoring smart structures utilizing distributed optical sensors
US6848510B2 (en) 2001-01-16 2005-02-01 Schlumberger Technology Corporation Screen and method having a partial screen wrap
US6481495B1 (en) 2000-09-25 2002-11-19 Robert W. Evans Downhole tool with electrical conductor
WO2002036935A1 (en) 2000-11-03 2002-05-10 Bechtel Bwxt Idaho, Llc Methods of performing downhole operations using orbital vibrator energy sources
US7417920B2 (en) 2001-03-13 2008-08-26 Baker Hughes Incorporated Reciprocating pulser for mud pulse telemetry
US20030035205A1 (en) 2001-08-20 2003-02-20 Zisk Edward J. Fiber optic sensor signal amplifier
CA2364339C (en) 2001-12-04 2007-02-13 Victor Koro An apparatus, system, and method for detecting and reimpressing electrical charge disturbances on a drill-pipe
GB2391880B (en) * 2002-08-13 2006-02-22 Reeves Wireline Tech Ltd Apparatuses and methods for deploying logging tools and signalling in boreholes
US6978832B2 (en) 2002-09-09 2005-12-27 Halliburton Energy Services, Inc. Downhole sensing with fiber in the formation
US7219729B2 (en) 2002-11-05 2007-05-22 Weatherford/Lamb, Inc. Permanent downhole deployment of optical sensors
US7028543B2 (en) 2003-01-21 2006-04-18 Weatherford/Lamb, Inc. System and method for monitoring performance of downhole equipment using fiber optic based sensors
US7240738B2 (en) 2003-01-28 2007-07-10 Baker Hughes Incorporated Self-orienting selectable locating collet and method for location within a wellbore
US6970398B2 (en) 2003-02-07 2005-11-29 Schlumberger Technology Corporation Pressure pulse generator for downhole tool
US6915686B2 (en) 2003-02-11 2005-07-12 Optoplan A.S. Downhole sub for instrumentation
US7195033B2 (en) 2003-02-24 2007-03-27 Weatherford/Lamb, Inc. Method and system for determining and controlling position of valve
US7254999B2 (en) 2003-03-14 2007-08-14 Weatherford/Lamb, Inc. Permanently installed in-well fiber optic accelerometer-based seismic sensing apparatus and associated method
US7000698B2 (en) 2003-04-07 2006-02-21 Weatherford/Lamb, Inc. Methods and systems for optical endpoint detection of a sliding sleeve valve
US7436320B2 (en) 2003-06-16 2008-10-14 Baker Hughes Incorporated Sensor system and method of communicating data between a downhole device on a remote location
GB2436473B (en) 2003-06-16 2007-12-12 Baker Hughes Inc A sensor system and method of communicating data between a downhole device on a remote location
US7782709B2 (en) * 2003-08-22 2010-08-24 Schlumberger Technology Corporation Multi-physics inversion processing to predict pore pressure ahead of the drill bit
US7054011B2 (en) 2003-09-04 2006-05-30 Virginia Tech Intellectual Properties, Inc. Optical fiber pressure and acceleration sensor fabricated on a fiber endface
US7245382B2 (en) 2003-10-24 2007-07-17 Optoplan As Downhole optical sensor system with reference
GB0407982D0 (en) 2004-04-08 2004-05-12 Wood Group Logging Services In "Methods of monitoring downhole conditions"
US7367393B2 (en) 2004-06-01 2008-05-06 Baker Hughes Incorporated Pressure monitoring of control lines for tool position feedback
US7228900B2 (en) 2004-06-15 2007-06-12 Halliburton Energy Services, Inc. System and method for determining downhole conditions
US7441628B2 (en) 2004-10-14 2008-10-28 Z-Seis Corporation Wellbore signal generator
US7278480B2 (en) 2005-03-31 2007-10-09 Schlumberger Technology Corporation Apparatus and method for sensing downhole parameters
US7284606B2 (en) 2005-04-12 2007-10-23 Baker Hughes Incorporated Downhole position locating device with fluid metering feature
US20070012460A1 (en) 2005-07-13 2007-01-18 Baker Hughes Incorporated Hydrostatic-set open hole packer with electric, hydraulic and/or optical feed throughs
US7559358B2 (en) 2005-08-03 2009-07-14 Baker Hughes Incorporated Downhole uses of electroactive polymers
US7472589B2 (en) 2005-11-07 2009-01-06 Halliburton Energy Services, Inc. Single phase fluid sampling apparatus and method for use of same
US7740064B2 (en) 2006-05-24 2010-06-22 Baker Hughes Incorporated System, method, and apparatus for downhole submersible pump having fiber optic communications
US7881155B2 (en) 2006-07-26 2011-02-01 Welltronics Applications LLC Pressure release encoding system for communicating downhole information through a wellbore to a surface location
US7610960B2 (en) 2007-04-25 2009-11-03 Baker Hughes Incorporated Depth correlation device for fiber optic line
US7565834B2 (en) 2007-05-21 2009-07-28 Schlumberger Technology Corporation Methods and systems for investigating downhole conditions
US8497685B2 (en) 2007-05-22 2013-07-30 Schlumberger Technology Corporation Angular position sensor for a downhole tool
US20090034368A1 (en) 2007-08-02 2009-02-05 Baker Hughes Incorporated Apparatus and method for communicating data between a well and the surface using pressure pulses
US8733438B2 (en) 2007-09-18 2014-05-27 Schlumberger Technology Corporation System and method for obtaining load measurements in a wellbore
US8196656B2 (en) 2007-09-19 2012-06-12 Welldynamics, Inc. Position sensor for well tools
US7946341B2 (en) 2007-11-02 2011-05-24 Schlumberger Technology Corporation Systems and methods for distributed interferometric acoustic monitoring
US8237443B2 (en) 2007-11-16 2012-08-07 Baker Hughes Incorporated Position sensor for a downhole completion device
WO2009128977A2 (en) 2008-02-12 2009-10-22 Baker Hughes Incorporated Fiber optic sensor system using white light interferometery
US20090201764A1 (en) 2008-02-13 2009-08-13 Baker Hughes Incorporated Down hole mud sound speed measurement by using acoustic sensors with differentiated standoff
US9546548B2 (en) 2008-11-06 2017-01-17 Schlumberger Technology Corporation Methods for locating a cement sheath in a cased wellbore
US20100166358A1 (en) 2008-12-30 2010-07-01 Daniel Homa Dual Fiber Grating and Methods of Making and Using Same
US20120037360A1 (en) 2009-04-24 2012-02-16 Arizmendi Jr Napoleon Actuators and related methods
US8109333B2 (en) 2009-05-07 2012-02-07 Baker Hughes Incorporated Indicator and method
US20100303426A1 (en) 2009-05-29 2010-12-02 Baker Hughes Incorporated Downhole optical fiber spice housing
US9175520B2 (en) 2009-09-30 2015-11-03 Baker Hughes Incorporated Remotely controlled apparatus for downhole applications, components for such apparatus, remote status indication devices for such apparatus, and related methods
CA2785651C (en) * 2009-12-28 2018-06-12 Schlumberger Canada Limited Downhole data transmission system
US8274400B2 (en) 2010-01-05 2012-09-25 Schlumberger Technology Corporation Methods and systems for downhole telemetry
US8430163B2 (en) 2010-03-12 2013-04-30 Schlumberger Technology Corporation Downhole acoustic sensing tool and method
US8960313B2 (en) 2010-03-15 2015-02-24 Schlumberger Technology Corporation Packer deployed formation sensor
US20110280105A1 (en) 2010-05-12 2011-11-17 Hall David R Downhole Turbine Communication
US20120046866A1 (en) 2010-08-23 2012-02-23 Schlumberger Technology Corporation Oilfield applications for distributed vibration sensing technology
US8875791B2 (en) 2010-10-18 2014-11-04 Schlumberger Technology Corporation Segmented fiber optic coiled tubing assembly
US8740455B2 (en) 2010-12-08 2014-06-03 Baker Hughes Incorporated System and method for distributed environmental parameter measurement
US8910716B2 (en) 2010-12-16 2014-12-16 Baker Hughes Incorporated Apparatus and method for controlling fluid flow from a formation
US20120176250A1 (en) 2011-01-06 2012-07-12 Baker Hughes Incorporated System and method for integrated downhole sensing and optical fiber monitoring
US8797541B2 (en) 2011-07-11 2014-08-05 Baker Hughes Incorporated Optical network configuration with intrinsic delay for swept-wavelength interferometry systems
US10180061B2 (en) 2011-09-26 2019-01-15 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US9297767B2 (en) 2011-10-05 2016-03-29 Halliburton Energy Services, Inc. Downhole species selective optical fiber sensor systems and methods
US20140014329A1 (en) 2012-07-10 2014-01-16 Baker Hughes Incorporated Landing indicator for logging tools
AU2013298346B2 (en) 2012-07-31 2016-07-07 Weatherford Technology Holdings, Llc Downhole apparatus and method
US9347309B2 (en) 2013-03-11 2016-05-24 Weatherford Technology Holdings, Llc Cement plug location
US20150077265A1 (en) * 2013-09-19 2015-03-19 Halliburton Energy Services, Inc. Telemetry on tubing
US9726004B2 (en) 2013-11-05 2017-08-08 Halliburton Energy Services, Inc. Downhole position sensor
GB2536817B (en) 2013-12-30 2021-02-17 Halliburton Energy Services Inc Position indicator through acoustics
WO2015112127A1 (en) 2014-01-22 2015-07-30 Halliburton Energy Services, Inc. Remote tool position and tool status indication

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6177882B1 (en) * 1997-12-01 2001-01-23 Halliburton Energy Services, Inc. Electromagnetic-to-acoustic and acoustic-to-electromagnetic repeaters and methods for use of same
US6018501A (en) * 1997-12-10 2000-01-25 Halliburton Energy Services, Inc. Subsea repeater and method for use of the same
US6075461A (en) * 1997-12-29 2000-06-13 Halliburton Energy Services, Inc. Disposable electromagnetic signal repeater
US20100309019A1 (en) * 2004-07-01 2010-12-09 Halliburton Energy Services, Inc. Acoustic telemetry transceiver
US20100013663A1 (en) * 2008-07-16 2010-01-21 Halliburton Energy Services, Inc. Downhole Telemetry System Using an Optically Transmissive Fluid Media and Method for Use of Same

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9726004B2 (en) 2013-11-05 2017-08-08 Halliburton Energy Services, Inc. Downhole position sensor
US9784095B2 (en) 2013-12-30 2017-10-10 Halliburton Energy Services, Inc. Position indicator through acoustics
US10683746B2 (en) 2013-12-30 2020-06-16 Halliburton Energy Services, Inc. Position indicator through acoustics
US10119390B2 (en) 2014-01-22 2018-11-06 Halliburton Energy Services, Inc. Remote tool position and tool status indication
CN107366532A (en) * 2017-07-17 2017-11-21 中国石油大学(华东) Oil-gas pipeline sand production rate monitors experimental provision and monitoring method
CN107366532B (en) * 2017-07-17 2020-08-04 中国石油大学(华东) Oil-gas pipeline sand output monitoring experimental device and monitoring method

Also Published As

Publication number Publication date
GB2537494B (en) 2020-09-16
US9650889B2 (en) 2017-05-16
US20160273350A1 (en) 2016-09-22
GB2537494A (en) 2016-10-19

Similar Documents

Publication Publication Date Title
AU2022231723B2 (en) Method and system for downhole object location and orientation determination
US9650889B2 (en) Downhole signal repeater
CA2726694A1 (en) Seismic location and communication system
GB2546061A (en) Method and system for downhole object location and orientation determination
CN102449263A (en) Well monitoring by means of distributed sensing means
US11713673B2 (en) Devices, systems, and methods for downhole event detection and depth determination
CN104094137A (en) Optical fiber well deployment for seismic surveying
US20110310701A1 (en) Seismic Telemetry and Communications System
GB2604059A (en) Bi-directional acoustic telemetry system
CA2999248C (en) Real-time bottom-hole flow measurements for hydraulic fracturing with a doppler sensor in bridge plug using das communication
WO2008097352A1 (en) Apparatus and method for generating a seismic signal
US10119390B2 (en) Remote tool position and tool status indication
RU2016147666A (en) WELL CONTROL SYSTEM
CN114089438B (en) Intelligent monitoring system for coal mine land survey prevention and control water
CN114555910A (en) Information transmission system
GB2536710A (en) Intervention monitoring system

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 14413906

Country of ref document: US

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 13900471

Country of ref document: EP

Kind code of ref document: A1

ENP Entry into the national phase

Ref document number: 201605452

Country of ref document: GB

Kind code of ref document: A

Free format text: PCT FILING DATE = 20131223

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 13900471

Country of ref document: EP

Kind code of ref document: A1