WELLBORE TELEMETRY SYSTEM AND METHOD
Wellbore communication systems and methods for a wellsite having a downhole tool deployed from a rig into a wellbore penetrating a subterranean formation are disclosed. One example communication system includes a first mud pulse telemetry device positioned in a downhole tool and at least one additional non-mud pulse telemetry device positioned in the downhole tool. The example system also includes at least one of a pressure transducer or a pressure sensor adapted to detect a modulated pressure provided by at least one of the telemetry devices.
Latest SCHLUMBERGER TECHNOLOGY CORPORATION Patents:
This application claims priority to U.S. Provisional Application Ser. No. 60/697,073, filed on Jul. 5, 2005 and entitled “WELLBORE TELEMETRY SYSTEM AND METHOD.”
FIELD OF THE DISCLOSUREThe present disclosure relates to telemetry systems and methods for use in wellbore operations. More particularly, the present disclosure relates to wellbore telemetry systems and methods for conveying signals between a surface unit and a downhole tool.
BACKGROUNDWellbores may be drilled to locate and produce hydrocarbons. Typically, a wellbore is formed by advancing a downhole drilling tool having a drill bit at one end into the ground. As the drilling tool is advanced, drilling fluid (“mud”) is pumped from a surface mud pit through a passage or passages in the drilling tool and out the drill bit. The mud exiting the drill bit flows back to the surface to be returned to the mud pit and may be re-circulated through the drilling tool. In this manner, the drilling mud cools the drilling tool, carries cuttings and other debris away from the drilling tool, and deposits the cuttings and other debris in the mud pit. As is known, in addition to the cooling and cleaning operations performed by the mud pumped into the wellbore, the mud forms a mudcake that lines the wellbore which, among other functions, reduces friction between the drill string and subterranean formations.
During drilling operations (i.e., advancement of the downhole drilling tool), communications between the downhole drilling tool and a surface-based processing unit and/or other surface devices may be performed using a telemetry system. In general, such telemetry systems enable the conveyance of power, data, commands, and/or any other signals or information between the downhole drilling tools/bottom hole assemble (BHA) and the surface devices. Thus, the telemetry systems enable, for example, data related to the conditions of the wellbore and/or the downhole drilling tool to be conveyed to the surface devices for further processing, display, etc. and also enable the operations of the downhole drilling tool to be controlled via commands and/or other information sent from the surface device(s) to the downhole drilling tool.
One known wellbore telemetry system 100 is depicted in
As shown in
In addition to the known mud pulse telemetry system 100 depicted in
Despite the development and advancement of wellbore telemetry devices in wellbore operations, there remains a need for additional reliability and wellbore telemetry capabilities for wellbore operations. As with other many other wellbore devices, wellbore telemetry devices sometimes fail. Additionally, the power provided by many known wellbore telemetry devices may be insufficient to power desired wellbore operations. Attempts have been made to use two different types of mud pulse telemetry devices in a downhole tool. In particular, each of the different mud pulse telemetry devices is typically positioned in the downhole tool and communicatively linked to a different, respective surface unit. Such wellbore telemetry tools have been run simultaneously and non-simultaneously and at different frequencies. Attempts have also been made to develop dual channel downhole wellbore telemetry for transmitting data streams via communication channels to be interpreted independently as described in U.S. Pat. No. 6,909,667.
Despite the above-noted advancements in wellbore telemetry systems, there remains a need to provide wellbore telemetry systems capable of providing added reliability, increased speed, and increased power capabilities. As set forth in the detailed description below, the example methods and apparatus enable telemetry systems to operate at one or more desired frequencies and provide increased bandwidth. Additionally, the example methods and apparatus described below enable a plurality of different wellbore telemetry devices to be combined with a variety of one or more downhole components, such as formation evaluation tools, to provide flexibility in performing wellbore operations. Still further, the example methods and apparatus described below provide backup wellbore telemetry capability, enable the operation of multiple identical or substantially similar wellbore telemetry tools, enable the generation of comparative wellbore measurements, enable the activation of multiple wellbore telemetry tools, increase the available bandwidth and/or data transmission rates for communications between one or more downhole tools and one or more surface units, and enable adaptation of the wellbore telemetry tools to different and/or varying wellbore conditions.
SUMMARYIn accordance with one disclosed example, a wellbore communication system for a wellsite having a downhole tool deployed in a wellbore penetrating a subterranean formation includes a first mud pulse telemetry device disposed in the downhole tool. The example system may also include at least one additional telemetry device other than a mud pulse telemetry device and disposed in the wellbore. Additionally, the example system may include at least one of a pressure transducer or a pressure sensor adapted to detect a modulated pressure provided by at least one of the telemetry devices.
In another disclosed example, a wellbore communication system for a wellsite having a downhole tool deployed in a wellbore penetrating a subterranean formation includes a plurality of wellbore telemetry systems. At least one of the wellbore telemetry systems may comprise a wired drill pipe telemetry system. The example system may also include at least one surface unit in communication with at least one of the plurality of wellbore telemetry systems.
In yet another disclosed example, a wellbore communication system for a wellsite having a downhole tool deployed in a wellbore penetrating a subterranean formation includes at least one formation evaluation component to measure at least one wellbore parameter. The example system may also include a plurality of wellbore telemetry systems. At least one of the wellbore telemetry systems may be in communication with the at least one formation evaluation component to receive data therefrom and to transmit the data to a surface unit.
In still another disclosed example, a method of communicating between a surface location and a downhole tool deployed in a wellbore penetrating a subterranean formation evaluates a subterranean formation using at least one downhole component positioned in the downhole tool. The downhole tool may comprise a plurality of wellbore telemetry systems. The example method may also selectively transmit data from the at least one downhole component to a surface unit via at least one of the wellbore telemetry systems.
BRIEF DESCRIPTION OF THE DRAWINGS
Certain examples are shown in the above-identified figures and described in detail below. In describing these examples, like or identical reference numbers are used to identify common or similar elements. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale or in schematic for clarity and/or conciseness.
Referring now to
Still further, while the surface unit 202 is depicted in the example of
Returning in detail to
In operation, the example wellbore telemetry system 20 of
In general, the example wellbore telemetry systems described herein may use telemetry devices arranged or positioned in various configurations relative to the downhole tool. In the example of
Turning again to the operation of the example system 200 of
As shown in
Turning in detail to the wired drill pipe wellbore telemetry system 348, it can be seen in the example of
During operation, either or both of the mud pulse telemetry device 338 and the wired drill pipe system 348 may be used to enable communications between the downhole tool 301 (e.g., the MWD tool 334) and the surface unit 302. Depending on the particular operational mode of the rig 10 and/or downhole or other environmental conditions, the device 338 or the system 348 may be best suited to convey data to the surface unit 302. Alternatively or additionally, both the device 338 and the system 348 may be used to convey information between the surface unit 302 and the downhole tool 301 at the same time. In such a case, the conveyed information may concern the same downhole parameter(s) or condition(s) or different parameter(s) or condition(s).
The mud pulse telemetry device 438 is position in the downhole tool 401 and may be implemented using the same device or a device similar to the device used to implement the device 38 of
The electromagnetic wellbore telemetry system 448 includes a downhole transceiver 454 and a surface transceiver 452. An example of an electromagnetic wellbore telemetry system that may be used to implement the system 448 of
While the example systems depicted in
Still further it should be understood that the telemetry devices, or any combination thereof, used with the example systems described herein may be positioned in various configurations about the downhole tool. For example, the devices may be positioned adjacent to each other or, alternatively, at some desired distance or spacing apart, with or without components disposed therebetween. The telemetry devices may be oriented vertically as shown in the examples, or one or more of the devices may be inverted.
A surface unit or computer 502, which may be similar or identical to one or more of the example surface units 202, 302, and 402 of
As depicted in
In the example of
Multiple wellbore telemetry devices and/or systems such as those described in connection with the example systems herein may be used to provide downhole tools with the ability to perform independent or integrated downhole operations. For example, one wellbore telemetry system and/or telemetry device may be used in conjunction with a downhole formation evaluation component to perform various testing operations, while a second telemetry device may be used to perform resistivity operations. Additional wellbore telemetry systems and/or devices may be provided as desired. In some cases it may be desirable to use certain wellbore telemetry systems or devices in conjunction with certain downhole components to perform certain downhole operations.
Measurements taking using the wellbore telemetry devices may be compared and analyzed. In this manner, duplicate or redundant measurements may be taken for calibration and/or verification purposes. Additionally, duplicate or redundant measurements may be taken at different positions (at the same or different times) to determine differences in the formation at various downhole locations. Measurements taken by different components may also be analyzed to determine, for example, performance capabilities and/or formation properties.
The separate or individual functionality of the wellbore telemetry devices may also be used to supply and/or enhance power capabilities for instruments or tools downhole/in the BHA as needed to perform continuous or additional operations. For example, embodiments of the systems disclosed herein may be implemented with a power source (e.g. batteries) or power generator (e.g. mud turbine), as known in the art, to provide the desired energy. Yet other embodiments may be implemented for power transmission via electromagnetic energy conveyance using the wired drill pipe systems disclosed herein.
Multiple wellbore telemetry devices may also be used to increase data transmission rates to the surface and/or to eliminate the need for batteries in the downhole tool. The use of multiple wellbore telemetry devices may also provide a backup system in a case where one of the wellbore telemetry systems fails or is otherwise unable to function properly. Further, in cases where two different wellbore telemetry systems and/or devices are used, alternative types of communications may be employed as desired or needed to provide more effective communications between a downhole tool and a surface unit. Still further, any desired communication medium (e.g., gas/gas mixtures including air, methane, nitrogen, mud, etc.) or combination of media may be used to implement the telemetry systems described herein. For example, any combination of wireless and/or hardwired media may be used to suit the needs of particular applications. More specifically, wireless media may include drilling mud, electromagnetic signals, acoustic signals, etc., and hardwired media may include wired drill pipe and/or any other media using electrical conductors. In some cases, especially when running under-balanced drilling, inert gas like nitrogen, methane or air is mixed to reduce the weight of the mud. If there is an excessive amount of gas in the mud system, mud pulse telemetry systems often fail to work. In some cases only pressurized gas is used for drilling. In these cases electromagnetic and/or wired drill pipe telemetry systems of the invention may be used. A combination of these telemetry systems or multiple electromagnetic or other telemetry devices can also be used as disclosed herein.
As noted above in connection with the examples of
One or more communication links may be provided to operatively couple the wellbore telemetry system(s) and/or device(s) to one or more surface unit(s). In this manner, each wellbore telemetry device and/or system can selectively communicate with one or more surface unit(s). Alternatively, such links may couple the wellbore telemetry system(s) and/or device(s). The telemetry device(s) may communicate with the surface via a wellbore telemetry system. Various communication links may be provided so that the wellbore telemetry devices and/or systems may communicate with each other and/or the surface unit(s) independently, simultaneously or substantially simultaneously, alternately (e.g., while one telemetry device is actively communicating, other telemetry devices are not actively communicating), and/or during selected (e.g., predetermined) time frames or intervals.
The signals and/or other communications conveyed via the example wellbore telemetry systems described herein may be used or manipulated to enable the efficient flow of data or information. For example, the example telemetry devices and/or systems may be selectively operated to pass data from the downhole tool to the surface unit or computer. Such data may be passed from the telemetry devices and/or systems at similar or different frequencies, simultaneously or substantially simultaneously, and/or independently. The data and/or signals may be selectively manipulated, analyzed, or otherwise processed to generate an optimum and/or desired data output. The data (e.g., the output data) may be compared (e.g., to reference values, threshold values, etc.) and/or analyzed to determine wellsite conditions, which may be used to adjust operating conditions, locate valuable hydrocarbons, and/or perform any other desired wellsite operations or functions.
It will be understood from the foregoing description that the example systems and methods described herein may be modified from the specific embodiments provided. For example, the communication links described herein may be wired or wireless. The example devices described herein may be manually and/or automatically activated or operated to perform the desired operations. Such activation may be performed as desired and/or based on data generated, conditions detected, and/or results from downhole operations.
The foregoing description and example systems and methods provided thereby are for purposes of illustration only and are not to be construed as limiting. Thus, although certain apparatus and methods have been described herein, the scope of coverage of this patent is not limited thereto. To the contrary, this patent covers all embodiments fairly falling within the scope of the appended claims either literally or under the doctrine of equivalents.
Claims
1. A wellbore communication system for a wellsite having a downhole tool deployed in a wellbore penetrating a subterranean formation, the communication system comprising:
- a first mud pulse telemetry device disposed in the downhole tool;
- at least one additional telemetry device other than a mud pulse telemetry device disposed in the wellbore; and
- at least one of a pressure transducer or a pressure sensor to detect a modulated pressure provided by the mud pulse telemetry device.
2. The communication system of claim 1, further comprising a surface unit to communicate with at least one of the telemetry devices.
3. The communication system of claim 1, further comprising at least one formation evaluation component to perform a downhole operation.
4. The communication system of claim 3, wherein at least one formation evaluation component is to be operatively coupled to at least one of the telemetry devices.
5. The communication system of claim 1, wherein at least one additional telemetry device comprises a telemetry system.
6. The communication system of claim 5, wherein the at least one additional telemetry system comprises an electromagnetic wellbore telemetry system.
7. The communication system of claim 5, wherein the at least one additional telemetry system comprises a wired drill pipe telemetry system.
8. The communication system of claim 1, further comprising at least one additional mud pulse telemetry device positioned in the downhole tool.
9. A wellbore communication system for a wellsite having a downhole tool deployed from a rig into a wellbore penetrating a subterranean formation, the communication system comprising:
- a plurality of wellbore telemetry systems, wherein at least one of the wellbore telemetry systems comprises a wired drill pipe telemetry system; and
- at least one surface unit in communication with at least one of the plurality of wellbore telemetry systems.
10. The communication system of claim 9, wherein the plurality of wellbore telemetry systems comprises one or more of another wired drill pipe telemetry system, a mud pulse telemetry system, or an electromagnetic telemetry system.
11. The communication system of claim 9, further comprising at least one formation evaluation component to perform a downhole operation.
12. The communication system of claim 11, wherein the at least one formation evaluation component is to be operatively coupled to at least one of the wellbore telemetry systems.
13. A wellbore communication system for a wellsite having a downhole tool deployed in a wellbore penetrating a subterranean formation, the communication system comprising:
- at least one formation evaluation component to measure at least one wellbore parameter; and
- a plurality of wellbore telemetry systems, wherein at least one of the wellbore telemetry systems is to be in communication with the at least one formation evaluation component to receive data therefrom and to transmit the data to a surface unit.
14. The communication system of claim 13, wherein the wellbore telemetry systems comprise one or more of a mud pulse telemetry system, an electromagnetic telemetry system, or a wired drill pipe telemetry system.
15. The communication system of claim 13, wherein each formation evaluation tool is to be operatively coupled to a respective wellbore telemetry device.
16. A method of communicating between a surface location and a downhole tool deployed in a wellbore penetrating a subterranean formation, the method comprising:
- evaluating a subterranean formation using at least one downhole component positioned in the downhole tool, wherein the downhole tool comprises a plurality of wellbore telemetry systems; and
- selectively transmitting data from the at least one downhole component to a surface unit of at least one of the wellbore telemetry systems.
17. The method of claim 16, wherein the data is transmitted simultaneously from each downhole component.
18. The method of claim 16, wherein the data is transmitted at different times from at least two downhole components.
19. The method of claim 16, further comprising transmitting the data between wellbore telemetry devices.
20. The method of claim 16 further comprising analyzing data collected from the at least one formation evaluation component.
21. The method of claim 20, wherein the data from each formation evaluation component is compared.
22. The method of claim 16, further comprising supplying power to a downhole tool using one of the plurality of wellbore telemetry systems.
23. A wellbore telemetry system, comprising:
- a first wellbore telemetry device coupled to a downhole tool and adapted to use a communication medium to communicate with a surface computer; and
- a second wellbore telemetry device coupled to a downhole tool and adapted to use one of the communication medium, a wired drill pipe communication link, or an electromagnetic communication link to communicate with the surface computer.
24. The wellbore telemetry system of claim 23, wherein the downhole tool comprises at least two measurement while drilling tools.
25. The wellbore telemetry system of claim 23, wherein the communication medium comprises mud in a wellbore.
26. The wellbore telemetry system of claim 23, wherein the communication medium comprises a mixture of mud and gas in a wellbore.
27. The wellbore telemetry system of claim 23, wherein the communication medium comprises a gas consisting substantially of nitrogen, methane, or air in a wellbore.
28. The wellbore telemetry system of claim 24, wherein the first and second wellbore telemetry devices comprise at least one of mud pulse telemetry devices, sirens, positive pulse devices, or negative pulse devices.
Type: Application
Filed: May 10, 2006
Publication Date: Jan 25, 2007
Applicant: SCHLUMBERGER TECHNOLOGY CORPORATION (SUGAR LAND, TX)
Inventors: BRIAN CLARK (SUGAR LAND, TX), LUCIAN JOHNSTON (SUGAR LAND, TX), REMI HUTIN (NEW ULM, TX), NICOLAS PACAULT (MONTROUGE), PABLO CODESAL (AL KHOBAR), STEVE GOMEZ (HOUSTON, TX), RANDALL LEBLANC (KATY, TX)
Application Number: 11/382,598
International Classification: E21B 43/00 (20060101);