US 20090173493 A1
A downhole interface is disclosed that is positionable between a downhole tool, such as a wireline tool, and a wired drill string. The downhole tool communicates with the downhole interface which in turn communicates with the wired drill string to transmit information to the Earth's surface. The interface provides signal and power communication to the downhole tool.
1. A system for transmitting information from a downhole tool in a wellbore to a surface location:
a downhole tool positioned in the borehole;
a downhole interface communicatively coupled to the downhole tool; and
a plurality of wired dill pipes communicatively coupled to the downhole interface, wherein the downhole interface is positioned between the downhole tool and the plurality of wired drill pipes, and further wherein the downhole tool communicates with the downhole interface to transmit information along the plurality of wired drill pipes.
2. The system of
3. The system of
4. The system of
5. The system of
6. The system of
7. The system of
8. The system of
9. The system of
10. A system for providing communication in a borehole comprising:
a drill string comprising at least a portion of wired drill pipes communicatively coupled;
a downhole interface communicatively coupled to one of the wired drill pipes; and
a wireline tool communicatively coupled to the downhole interface, the wireline tool deployable on the drill string.
11. The system of
12. The system of
13. The system of
14. The system of
15. The system of
16. A method for transmitting information from a wellbore below the Earth's surface comprising:
communicatively coupling a wireline tool to a downhole interface;
communicatively coupling the downhole interface between a drill string comprising a plurality of wired drill pipes and the downhole interface, the downhole interface directly coupled to the wireline tool and the plurality of wired drill pipes;
measuring a characteristic of the wellbore with the wireline tool;
transmitting a signal related to the characteristic of the wellbore to the downhole interface; and
transmitting the signal from the downhole interface to the plurality of wired drill pipes.
17. The method of
18. The method of
19. The method of
20. The method of
The present application is a continuation application and claims priority from U.S. patent application Ser. No. 11/688,089, entitled “Completion System Having a Sand Control Assembly, An Inductive Coupler, And a Sensor Proximate to the Sand Control Assembly,” filed on Mar. 19, 2007, and U.S. patent Ser. No. 11/995,027, entitled “Interface and Method for Wellbore Telemetry System,” filed on Aug. 3, 2006, which are both hereby incorporated by reference in their entireties.
U.S. patent application Ser. No. 11/688,089 claims priority to U.S. Provisional Application Nos. 60/787,592, filed on Mar. 30, 2006; 60/745,469 filed on Apr. 24, 2006; 60/747,986, filed on May 23, 2006; 60/805,691, filed on Jun. 23, 2006; 60/805,691, filed on Jun. 23, 2006; 60/865,622, filed on Nov. 21, 2006; 60/867,276, filed on Nov. 27, 2006; and 60/890,630, filed on Feb. 20, 2007, which are each hereby incorporated by reference in their entireties.
U.S. patent application Ser. No. 11/995,027 claims priority to Provisional Patent Application No. 60/705,326, filed Aug. 4, 2005, and also claims priority from U.S. Provisional Patent Application No. 60/708,561, filed Aug. 16, 2005, both of which are incorporated herein by reference its entirety.
Also, the present Application contains subject matter that relates to subject matter disclosed in copending U.S. patent application Ser. No. 11/498,845 and copending U.S. patent application Ser. No. 11/498,847.
The present invention relates to telemetry systems for use in wellbore operations. More particularly, the present invention relates to wellbore telemetry systems for transmitting signals between a surface processor unit and a downhole tool positionable in a wellbore.
Wellbores are drilled to locate and produce hydrocarbons. A downhole drilling tool with a bit at one end thereof is advanced into the ground via a drill string to form a wellbore. The drill string and the downhole tool are typically made of a series of drill pipes threadably connected together to form a long tube with the bit at the lower end thereof. As the drilling tool is advanced, a drilling mud is pumped from a surface mud pit, through the drill string and the drilling tool and out the drill bit to cool the drilling tool and carry away cuttings. The fluid exits the drill bit and flows back up to the surface for recirculation through the tool. The drilling mud is also used to form a mudcake to line the wellbore.
During the drilling operation, it is desirable to provide communication between the surface and the downhole tool. Wellbore telemetry devices are typically used to allow, for example, power, command and/or communication signals to pass between a surface unit and the downhole tool. These signals are used to control and/or power the operation of the downhole tool and send downhole information to the surface.
Various wellbore telemetry systems may be used to establish the desired communication capabilities. Examples of such systems may include a wired drill pipe wellbore telemetry system as described in U.S. Pat. No. 6,641,434, an electromagnetic wellbore telemetry system as described in U.S. Pat. No. 5,624,051, an acoustic wellbore telemetry system as described in PCT Patent Application No. WO2004085796, the entire contents of which are hereby incorporated by reference. Other data conveyance or communication devices, such as transceivers coupled to sensors, may also be used to transmit power and/or data.
With wired drill pipe (“WDP”) telemetry systems, the drill pipes that form the drill string are provided with electronics capable of passing a signal between a surface unit and the downhole tool. As shown, for example, in U.S. Pat. No. 6,641,434, such wired drill pipe telemetry systems can be provided with wires and inductive couplings that form a communication chain that extends through the drill string. The wired drill pipe is then operatively connected to the downhole tool and a surface unit for communication therewith. The wired drill pipe system is adapted to pass data received from components in the downhole tool to the surface unit and commands generated by the surface unit to the downhole tool. Further documents relating to wired drill pipes and/or inductive couplers in a drill string are as follows: U.S. Pat. No. 4,126,848, U.S. Pat. No. 3,957,118 and U.S. Pat. No. 3,807,502, the publication “Four Different Systems Used for MWD,” W. J. McDonald, The Oil and Gas Journal, pages 115-124, Apr. 3, 1978, U.S. Pat. No. 4,605,268, Russian Federation Published Patent Application 2140527, filed Dec. 18, 1997, Russian Federation Published Patent Application 2,040,691, filed Feb. 14, 1992, WO Publication 90/14497A2, U.S. Pat. No. 5,052,941, U.S. Pat. No. 4,806,928, U.S. Pat. No. 4,901,069, U.S. Pat. No. 5,531,592, U.S. Pat. No. 5,278,550, and U.S. Pat. No. 5,971,072.
With the advent and expected growth of wired drill pipe technology, various types of circumstances will arise where it is necessary to connect a section of wired drill pipe to various types of uphole equipment or various types of tools or other downhole equipment. In some cases, the wired drill pipe may be incompatible with one or more components in the downhole tool and/or surface units.
It is, therefore, desirable to provide an interface to establish a communication link between a section of the wired drill pipe and the downhole tool and/or surface unit to facilitate communication between the downhole tool and a surface unit. It is further desirable to provide wellbore telemetry systems capable of providing added reliability, increased data rate, compatibility between a variety of downhole systems and increased power capabilities. Such a system is preferably capable of one or more of the following, among others: improving reliability, reducing communication failures, improving connectability, increase bandwidth, increase data rates, providing flexibility for a variety of downhole configurations and adapting wellbore telemetry tools to various wellsite configurations.
So that the above recited features and advantages of the present invention can be understood in detail, a more particular description of the invention, briefly summarized above, may be had by reference to the embodiments thereof that are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this invention and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments.
Presently preferred embodiments of the invention are shown in the above-identified figures and described in detail below. In describing the preferred embodiments, like or identical reference numerals 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 in the interest of clarity and conciseness.
The downhole system 3 includes a drill string 12 suspended within the borehole 11 with a drill bit 15 at its lower end. The surface system 2 includes the land-based platform and derrick assembly 10 positioned over the borehole 11 penetrating a subsurface formation F. The assembly 10 includes a rotary table 16, kelly 17, hook 18 and rotary swivel 19. The drill string 12 is rotated by the rotary table 16, energized by means not shown, which engages the kelly 17 at the upper end of the drill string. The drill string 12 is suspended from a hook 18, attached to a traveling block (also not shown), through the kelly 17 and a rotary swivel 19 which permits rotation of the drill string relative to the hook.
The surface system further includes drilling fluid or mud 26 stored in a pit 27 formed at the well site. A pump 29 delivers the drilling fluid 26 to the interior of the drill string 12 via a port in the swivel 19, inducing the drilling fluid to flow downwardly through the drill string 12 as indicated by the directional arrow 9. The drilling fluid exits the drill string 12 via ports in the drill bit 15, and then circulates upwardly through the region between the outside of the drill string and the wall of the borehole, called the annulus, as indicated by the directional arrows 32. In this manner, the drilling fluid lubricates the drill bit 15 and carries formation cuttings up to the surface as it is returned to the pit 27 for recirculation.
Below the drill string 12, there is a bottom hole assembly (BHA), generally referred to as 100, near the drill bit 15 (in other words, within several drill collar lengths from the drill bit). The bottom hole assembly includes capabilities for measuring, processing, and storing information, as well as communicating with the surface. The BHA 100 thus includes, among other things, an apparatus 110 for determining and communicating one or more properties of the formation F surrounding borehole 11, such as formation resistivity (or conductivity), natural radiation, density (gamma ray or neutron), and pore pressure.
The BHA 100 further includes drill collar 150 for performing various other measurement functions. Drill collar 150 houses a measurement-while-drilling (MWD) tool. The MWD tool further includes an apparatus (not shown) for generating electrical power to the downhole system. While a mud pulse system is depicted with a generator powered by the flow of the drilling fluid 26 that flows through the drill string 12 and the MWD drill collar 150, other power and/or battery systems may be employed.
Sensors may be provided about the wellsite to collect data, preferably in real time, concerning the operation of the wellsite, as well as conditions at the wellsite. For example, such surface sensors may be provided to measure standpipe pressure, hookload, depth, surface torque, rotary rpm, among others. Downhole sensors may be disposed about the drilling tool and/or wellbore to provide information about downhole conditions, such as wellbore pressure, weight on bit, torque on bit, direction, inclination, drill collar rpm, tool temperature, annular temperature and toolface, among others. The information collected by the sensors are conveyed to the surface system, the downhole system and/or the surface control unit.
As shown in
While only one surface unit 4 at one wellsite 1 is shown, one or more surface units across one or more wellsites may be provided. The surface units may be linked to one or more surface interface using a wired or wireless connection via one or more communication lines 130. The communication topology between the surface interface and the surface system can be point-to-point, point-to-multipoint or multipoint-to-point. The wired connection includes the use of any type of cables (wires using any type of protocols (serial, Ethernet, etc.) and optical fibers. The wireless technology can be any kind of standard wireless communication technology, such as IEEE 802.11 specification, Bluetooth, zigbee or any non-standard RF or optical communication technology using any kid of modulation scheme, such as FM, AM, PM, FSK, QAM, DMT, OFDM, etc. in combination with any kind of data multiplexing technologies such as TDMA, FDMA, CDMA, etc. As one example, the antenna for the wireless connection can be put in the outer layer of the sub.
As shown in
The uphole interface 120 is shown in greater detail in
A WDP connector 208 is provided to operatively link the uphole interface with the wired drill pipe telemetry system. The connector may be an inductive coupler similar to the ones used on adjacent drill pipe in the WDP telemetry system. Alternatively, the connector may be a conductive connector or any other connector capable of communicating with the wired drill pipe telemetry system.
A surface connector 210 is also provided to operatively link the uphole interface with the surface unit. The surface connector may be a wired, wireless or optical connector adapted to link to the surface unit. The connector may provide for conductive, inductive, wired, wireless and/or optical communication with the surface unit.
One or more sensors 204 may be provided in the uphole interface 120 to measure various wellbore parameters, such as temperature, pressure (standpipe, mud telemetry, etc.), mud flow, noise, drilling mechanics (i.e., torque, weight on bit, acceleration, pipe rotation, etc.), etc. The measurements for drilling mechanics are performed at high sampling rates (typically 120 Hz). In addition, the pressure measurements are performed at higher sampling rates (typically 480 Hz) to facilitate telemetry demodulation. The sensors may be linked to an analog front end for signal conditioning and/or to a processor for processing and/or analyzing data. The sensors may also be used to perform diagnostics to locate faults in the wired drill pipe system, measure noise and/or characteristics of the wired drill pipe telemetry system and perform other diagnostics of the wellsite. The sensors may be integrated into the uphole interface 120 or placed along its outer diameter or inner diameter. Sensor data may be recorded in a memory device.
The uphole interface 120 may further be provided with a power module 206. The power module may generate power using any kind of power generator such as a turbine, piezoelectric, solar cell, etc., from any kind of potential energy source such as mud flow, rotation, vibration, RF signal, etc. The uphole interface may also be powered using batteries alone or as a backup of a power generator technique. The batteries may be rechargeable. Alternative power may be provided externally and stored or used by the uphole interface. In the wired drill pipe system, the uphole interface 120 may also be powered using a cable from a power generator located on or near the rig.
The surface modem 200 is adapted to communicate with one or more modems in the surface unit 4. The WDP uphole modem 202 is adapted to communicate with one or more modems, repeaters, or other interfaces in the downhole tool via the wired drill pipe telemetry system. Preferably, the modems provide bi-directional communications. Any kind of digital and analog modulation scheme may be used, such as biphase, frequency shift keying (FSK), quadrature phase shift-keying (QPSK), Quadrature Amplitude Modulation (QAM), discrete multi tone (DMT), etc. These schemes may be used in combination with any kind of data multiplexing technologies such as Time Division Multiplexing (TDM), Frequency Division Multiplexing (FDM), etc. The modem may include functionality for drill pipe diagnostics and downhole tool diagnostics.
The surface modem 200 is shown in greater detail in
The processor 304 of the modem is used to modulate and demodulate signals received from the downhole tool and/or surface unit for conversion so that they may be received by the downhole tool and surface unit. Error corrections, detection, compression, encryption and other data manipulation may be performed. The modulation scheme for the interface is preferably set at a baud rate capable of communicating between the surface unit and the downhole tool. The baud rates of corresponding modems for the surface unit and interface are provided with aligned baud rates. Similarly, the baud rates of the corresponding modems for the downhole tool and the uphole interface are aligned.
The memory unit 306 is provided to store data for future use. Sensor or diagnostic data, for example, may be stored.
Other items, such as a global positioning system 308, may also be provided to perform additional functions, such as setting a real time clock, or for time synchronization between uphole surface and downhole tools/surface units. Additionally, an analog front end (amplifiers, filters, etc.) may also be required.
Referring now to
The downhole interface 140 may be the same as the uphole interface, except that the downhole interface is provided with a WDP downhole modem 320, a downhole modem 322, a WDP connector 324 and a downhole tool connector 326. The downhole interface provides a communication link between the uphole interface and the downhole interface. The downhole modem provides a communication link between the WDP telemetry system and one or more components in the downhole tool. Additionally, a downhole connector 326 will be provided in place of the surface connector. The downhole connector may be wired or wireless and provide an inductive, conductive or optical connection between the WDP telemetry and the downhole tool. The WDP connector 324 operatively connects the downhole interface to the wired drill pipe telemetry system.
Communication between the interface(s) and the downhole tool and/or surface unit is performed according to a protocol. The protocol defines the format and sequence for signals that are sent and received by the interface. The protocol may be, for example, a predefined set of rules that establish the communication scheme between corresponding modems. The protocol may be selectively adjusted to conform to the requirements of a given telemetry system. Alternatively, a given telemetry system may be adapted to conform to the protocol of the interface. The protocol and/or baud rates for the downhole interface may be adjusted to the uphole interface, and the protocol and/or baud rates for the uphole interface may also be adjusted to the downhole interface.
The housing may be a drill collar or other tubing or sub connectable to the WDP system and/or downhole tool. Alternatively, the housing may be part of the WDP system and/or downhole tool. Preferably the ends 531 and 533 are threadably connected to corresponding drill pipes of the WDP system and/or downhole tool. As shown, ends 531 and 533 are box ends provided with mating internal threads adapted to threadably engage an adjacent drill pipe for operative connection therewith. The ends may optionally be box or pin ends as necessary to mate with adjacent collars. One or more such interface 500 may be connected together or separated by additional drill collars. The interface may be inverted, so long as the operative connections are mated to their respective tools.
The WDP connector 524 and the downhole connector 526 operatively connect the interface to the WDP system and the downhole tool, respectively. The electronics 550 are used to pass signals between the WDP system and the downhole tool. The electronics contain a WDP modem 520 and a downhole modem 522. Additional electronics may also be included, such as the electronics shown in
As shown in
The housing may be the same as in
The housing may be provided with one or more connections 660. The connections 660 provide modularity for the interface 600. Portions of the interface may be selectively connected or separated. The connections may be for example, shop joint, threaded, soldered, welded, or other joints that operatively connect portions of the interface. The connections permit separation of the interface as necessary, for example for maintenance or machining. For example, where a WDP system is developed by a first entity, the first entity may develop a WDP portion of the related interface, and where the downhole tool is developed by a second entity, that second entity may develop the downhole portion of the interface. In this manner, the interface may be separately manufactured and then jointly assembled. Electronics 650 a, 650 b are preferably positioned in separate modules to permit separate assembly. While two sets of electronics are depicted, additional modules with additional electronics may be provided.
One or more connectors, such as link 662, may be used to operatively connect the electronics 650 a and 650 b. Links 670 a and 670 b are provided to operatively connect the electronics 650 a to WDP connector 624 and electronics 650 b to downhole connector 626 b, respectively. The connections, links, read out ports or other devices may communicate via wired, wireless, or any type of connector that permits an operative connection. Where such connections extend across a connection 660, an additional joint may be used.
The WDP connector 624 and the downhole connector 626 a may be the same as the connectors 524, 526, respectively. Optionally, an additional or alternative downhole connector 626 b may be used, such as an inductive or conductive connector operatively connectable to the downhole tool. The electronics 650 a, 650 b are used to pass signals between the WDP system and the downhole tool. The electronics 650 a and 650 b are depicted as having a WDP modem 620 and a downhole modem 622, respectively to enable communication therethrough. Connectors, such as 624, 626 a and 626 b may be positioned at various locations within the interface, so long as an operative connection is provided.
Additional electronics may also be included, such as the electronics shown in
As shown in
As shown in
Centralizers 652 a, 652 b are provided to support the electronics 650 f in the housing. Centralizer 652 a may be, for example, supports positioned about the electronics. Centralizer 652 b may be, for example, a ring or spider used to support the electronics.
While the configurations shown in
The controller may be used for processing signals, analyzing data, controlling the power supply and performing other downhole operations. The diagnostics may be used for monitoring the electronics, the downhole tool, the WDP system and other related systems. The sensors may be the same as the sensors 204 of
The WDP portion 782 is provided with the WDP modem 720 and a signal/power interface 778 b that communicates with signal power interface 778 a of the downhole portion 780. Connector 762 is optionally provided to operatively connect the upper and lower portions. In some cases, this may be a field joint or other type of connector capable of passing signals between the portions 780, 782. The connection may be, for example, inductive, conductive or optical and wired or wireless.
The interfaces as shown in
These configurations allow, among other things, flexibility in adapting to a variety of downhole tools and wired drill pipe telemetry systems. In addition to the figure depicted, various combinations of integral and separate interfaces may be used. Multiple integral interfaces may also be used.
Measurement data can be received in real-time through the use of the wired drill pipe telemetry system 445 from the downhole tool 1500, or the data may be stored in memory in the downhole tool and downloaded at a later time. In an embodiment where the downhole tool 1500 is an intervention tool, the measurement data can be transmitted during an intervention process to help monitor the state of the intervention.
The lower completions section 1020 has a sensor assembly 1120 that has multiple sensors 1140 positioned at various discrete locations, for example, across a sand face. The downhole tool 1500 may be deployed in the wellbore to communicate with the sensors 1140. By monitoring the measurement data collected by sensors 1140, a well operator can be provided with real-time indications related to the downhole tool 1500. For example, the well operator may be provided with information related to sliding sleeve closing or opening, a packer being set or unset, or etc. In an embodiment, the intervention-based system can also be used to perform drillstem testing, with measurement data collected by the sensors 1140 transmitted to the earth surface during the test to allow the well operator to analyze results of the drillstem testing.
It will be understood from the foregoing description that various modifications and changes may be made in the preferred and alternative embodiments of the present invention without departing from its true spirit. For example, the communication links described herein may be wired or wireless. The devices included herein may be manually and/or automatically activated to perform the desired operation. The activation may be performed as desired and/or based on data generated, conditions detected and/or analysis of results from downhole operations.
This description is intended for purposes of illustration only and should not be construed in a limiting sense. The scope of this invention should be determined only by the language of the claims that follow. The term “comprising” within the claims is intended to mean “including at least” such that the recited listing of elements in a claim are an open group. “A,” “an” and other singular terms are intended to include the plural forms thereof unless specifically excluded.