Claims
- 1. A method of providing acoustic transmission of data in tubular, comprising:
a. deploying a monitoring device through a tubular to a predetermined position within the tubular, the monitoring device adapted to acoustically transmit data to a remote receiver; b. physically coupling a predetermined portion of the monitoring device to the tubular once the monitoring device reaches the predetermined position; and c. acoustically coupling data transmission between the monitoring device and a remote receiver through the tubular.
- 2. The method of claim 1, wherein deploying the monitoring device is at least one of (i) a permanent deployment or (ii) a temporary deployment.
- 3. The method of claim 1, wherein deploying the monitoring device further comprises using at least one of (i) a slick line, (ii) a coiled tubing, or (iii) an electric line.
- 4. The method of claim 1, wherein physically coupling the monitoring device to the tubular further comprises physically engaging a portion of the monitoring device with an interior surface of the tubular when the monitoring device is positioned to the predetermined position within the tubular.
- 5. The method of claim 4, further comprising:
a. securing the monitoring device to the interior surface of the tubular using the portion of the monitoring device; and b. disengaging the portion of the monitoring device from the interior surface of the tubular when the monitoring device is to be repositioned within the tubular.
- 6. The method of claim 5, wherein the disengaging occurs when the monitoring device is to be repositioned within the tubular.
- 7. The method of claim 5, wherein the portion of the monitoring device comprises a slip adapted to selectively engage the interior surface of the tubular by the monitoring device to secure the monitoring device to the interior surface of the tubular.
- 8. The method of claim 1, wherein the monitoring device is adapted to at least one of (i) obtain data representative of a local parameter or (ii) process data representative of a local parameter.
- 9. The method of claim 1, further comprising:
a. deploying a sensor; and b. transmitting data between the sensor and the monitoring device.
- 10. The method of claim 9, wherein the transmitting data between the sensor and the monitoring device is wireless.
- 11. The method of claim 1, wherein the data transmission further comprises a data transmission identifier.
- 12. A system for transmission of data from within a tubular, comprising:
a. deploying a monitoring device through a tubular in a hydrocarbon well, the deployment being at least one of (i) temporary or (ii) permanent; b. physically coupling the monitoring device to an interior portion of the tubular; c. acoustically coupling the physically coupled monitoring device to a remote receiver at least partially through the tubular; d. acoustically transmitting data between the monitoring device and the remote receiver; and e. processing the data received by the remote receiver.
- 13. The method of claim 12, further comprising transmitting processed data between the receiver and a data processor using at least one of (i) a local bus, (ii) an RS-232 connection, (iii) a local area networking connection, (iv) a cellular telephony connection, or (v) a satellite data transmission connection.
- 14. The method of claim 12, wherein acoustically transmitting data comprises at least one of (i) continuous data transmission or (ii) a master-slave configuration wherein the monitoring device waits for the remote receiver to address a specific monitoring device prior to a function being performed by the monitoring device.
- 15. The method of claim 12, further comprising:
a. monitoring a predetermined parameter indicative of a physical condition of the hydrocarbon well; and b. providing control, command, and communication functionality between the monitoring device and the remote receiver using at least one of (i) a microprocessor or (ii) a digital signal processor.
- 16. The method of claim 15, wherein the control, command, and communication functionality is directed to a downhole device, the control, command, and communication functionality further comprising at least one of (i) an actuation command, (ii) a modification of a state, or (iii) a change in a status.
- 17. The method of claim 15, wherein:
a. the remote receiver is located at the surface of the hydrocarbon well; and b. the acoustically transmitted data is transmitted from the remote receiver, the data further comprising at least one of (i) a command to a single monitoring device, (ii) a command to a plurality of monitoring devices, or (iii) non-command data.
- 18. The method of claim 12, further comprising providing a health monitor feature at least partially implemented within the monitoring device to check the status of a component of the monitoring device.
- 19. The method of claim 12, further comprising providing a shut down and sleep mode for the monitoring device to reduce power consumption for work when the monitoring device is permanently deployed.
- 20. The method of claim 12, wherein:
a. the monitoring device is inserted through tubing deployed in situ; and b. physically coupling further comprises using a mechanical coupler adapted to expand or retract a portion of the monitoring device, the mechanical coupler further adapted to couple an acoustic signal to a receiver mounted in the monitoring device when the monitoring device is physically coupled to the tubular.
- 21. The method of claim 15, wherein the monitoring comprises at least one of (i) formation evaluation or (ii) production parameters monitoring.
- 22. The method of claim 12, further comprising:
a. processing the data in real time; and b. displaying the processed data on a display located at a surface location.
- 23. The method of claim 12, further comprising using the transmitted data to optimize hydrocarbon production over the life of the hydrocarbon well.
- 24. The method of claim 12, wherein the monitoring further comprises monitoring a physical characteristic usable by at least one of (i) a pressure buildup test, (ii) a gravel pack operation, (iii) a frac pack operation, (iv) an artificial lift operation, or (v) a coil tubing application.
- 25. The method of claim 24, wherein, for build up tests, the monitoring device is deployed in a hydrocarbon well through tubing for monitoring pressure when the hydrocarbon well is shut in.
- 26. The method of claim 24, wherein for either a gravel pack or frac pack operation, the method further comprises:
a. positioning the monitoring device in a washpipe; b. deploying the monitoring device as part of a work string to perform the gravel pack or frac pack operation; and c. acoustically transmitting the data at least partially through the washpipe to a surface location.
- 27. The method of claim 26, further comprising deploying a gauge in communication with the monitoring device, the gauge deployed in at least one of (i) the well or (ii) the washpipe.
- 28. The method of claim 27, wherein the gauge is disposed at least partially within the monitoring device.
- 29. The method of claim 27, wherein the gauge comprises at least one of (i) a pressure sensor, (ii) a temperature sensor, (iii) a strain gauge, or (iv) a flow meter adapted to determine if the process is being done properly and the fluids are going to the intended location in the formations.
- 30. The method of claim 24, for the artificial lift operation, further comprising deploying a wireless retrievable gauge in communication with the monitoring device, the wireless retrievable gauge adapted to determine a production pressure to provide a fluid level indication for optimization of the artificial lift process.
- 31. The method of claim 30, wherein fluid level information is acquired useful for optimization of the artificial lifting process.
- 32. The method of claim 24, for the gravel pack operation, further comprising:
a. using the monitoring device to seal the tubular and set the path for surface gravel into an existing gravel pack; and b. using the monitoring device to assure that gravel is reaching its destination by monitoring at least one of (i) downhole pressure of (ii) downhole temperature.
- 33. The method of claim 24, for coil tubing applications, wherein:
a. the wireless device is interfaced with a coil tubing for transmission of data in real time through the coil tubing for processing at the surface; and b. the wireless device further comprises a plurality of sensors.
- 34. The method of claim 33, wherein the plurality of sensors are deployed as part of a device string and comprise at least one of (i) a sensor internal to the wireless device and (ii) a sensor external to the wireless device.
- 35. The method of claim 34, wherein the external sensor is attached to the wireless device via a cable.
- 36. The method of claim 33, the plurality of sensors further comprise a sensor adapted to determine at least one of (i) a location of a device string in the well or (ii) a characteristic of the formation.
- 37. The method of claim 36, wherein the sensor further comprises at least one of (i) a casing collar locator, (ii) a gamma ray detector, (iii) a pressure sensor, or (iv) a temperature sensor.
- 38. The method of claim 36, wherein the characteristic comprises at least one of (i) pressure or (ii) temperature.
- 39. A wireless transmission device adapted to provide a detected parameter obtained from inside a wellbore and transmit the information using a wireless communications method, comprising:
a. an acoustic wireless transceiver; and b. a selectively expandable acoustic coupler operatively in communication with the acoustic wireless transceiver, the acoustic coupler adapted to physically couple the acoustic wireless transceiver with an interior of a tubular and acoustically communicate data.
- 40. The wireless transmission device of claim 39, further comprising:
a. a housing adapted to contain the acoustic wireless transceiver; and b. a sensor disposed at least partially within the housing, the sensor operatively in communication with the acoustic wireless transceiver and adapted to detect a characteristic of a formation.
- 41. The wireless transmission device of claim 40, wherein the sensor further comprises at least one of (i) a casing collar locator, (ii) a gamma ray detector adapted to determine the location of the device string in the well, or (iii) a sensor adapted to detect a characteristic of the formation.
- 42. The wireless transmission device of claim 41, wherein the characteristic of the formation is at least one of (i) pressure or (ii) temperature.
- 43. The wireless transmission device of claim 40, wherein the sensor further comprises a sensor deployed as part of a device string as a built in sensor or external to the acoustic device but attached to the wireless transmission device via a cable where data from the sensor will be converted into acoustic information and transmitted acoustically through tubing to the surface.
- 44. The wireless transmission device of claim 39, wherein the selectively expandable acoustic coupler comprises a slip disposed at least partially on an outside of the wireless transmission device.
- 45. A downhole wireless system, comprising:
a. a wireless acoustic transmission device, further comprising:
i. a pressure vessel adapted to house a data processor, an acoustic transceiver operatively in communication with the data processor, and a sensor operatively in communication with the data processor, the pressure vessel adapted to moveably fit within a tubular; and ii. a selectively expandable acoustic coupler adapted to selectively secure the pressure vessel against an interior of a tubular and couple an acoustic signal from the acoustic transceiver to the production tubing; and b. a surface processor adapted to obtain and process data obtained acoustically using the tubular as a transmission medium from at least one of (i) downhole or (ii) a surface sensor.
- 46. The downhole wireless system of claim 45, further comprising:
a. a power converter; and b. a data acquisition module.
- 47. The downhole wireless system of claim 45, wherein the acoustic transceiver comprises a data and control communications transceiver.
- 48. The downhole wireless system of claim 45, further comprising a downhole gauge operatively in communication with the data processor.
- 49. The downhole wireless system of claim 45, further comprising a low power microprocessor for control and communications of the downhole device.
- 50. The downhole wireless system of claim 45, wherein:
a. the data processor further comprises memory; and b. the acoustic transceiver is adapted to drive a piezoelectric assembly for transmission of acoustic signals between the acoustic transceiver and the surface using the tubular as a transmission medium.
PRIORITY INFORMATION
[0001] This application claims the benefit of U.S. Provisional Application No. 60/474,486 filed on Jun. 3, 2003.
Provisional Applications (1)
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Number |
Date |
Country |
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60475441 |
Jun 2003 |
US |