U.S. patent application number 12/401185 was filed with the patent office on 2009-07-09 for interface and method for transmitting information to and from a downhole tool.
Invention is credited to Jean-Marc Follini, Remi Hutin, Lise Hvatum, Raghu Madhavan, Christopher P. Reed, David Santoso.
Application Number | 20090173493 12/401185 |
Document ID | / |
Family ID | 40843658 |
Filed Date | 2009-07-09 |
United States Patent
Application |
20090173493 |
Kind Code |
A1 |
Hutin; Remi ; et
al. |
July 9, 2009 |
INTERFACE AND METHOD FOR TRANSMITTING INFORMATION TO AND FROM A
DOWNHOLE TOOL
Abstract
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.
Inventors: |
Hutin; Remi; (Burres Sur
Yvette, FR) ; Santoso; David; (Kanagawa, JP) ;
Hvatum; Lise; (Katy, TX) ; Reed; Christopher P.;
(West University Place, TX) ; Madhavan; Raghu;
(Kanagawa, JP) ; Follini; Jean-Marc; (Houston,
TX) |
Correspondence
Address: |
SCHLUMBERGER OILFIELD SERVICES
200 GILLINGHAM LANE, MD 200-9
SUGAR LAND
TX
77478
US
|
Family ID: |
40843658 |
Appl. No.: |
12/401185 |
Filed: |
March 10, 2009 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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11995027 |
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12401185 |
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11688089 |
Mar 19, 2007 |
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11995027 |
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Current U.S.
Class: |
166/250.01 ;
166/65.1 |
Current CPC
Class: |
E21B 17/003 20130101;
E21B 47/13 20200501; E21B 17/028 20130101 |
Class at
Publication: |
166/250.01 ;
166/65.1 |
International
Class: |
E21B 47/12 20060101
E21B047/12; E21B 41/00 20060101 E21B041/00; E21B 47/00 20060101
E21B047/00; E21B 49/00 20060101 E21B049/00 |
Claims
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 claim 1 wherein the downhole tool is a wireline
tool.
3. The system of claim 2 wherein the wireline tool is an
intervention tool.
4. The system of claim 3 wherein the intervention tool is
positioned within a lower completion section.
5. The system of claim 4 wherein the lower completion section is
incorporated into a portion of at least one of the plurality of
wired drill pipes.
6. The system of claim 4 further comprising a plurality of sensors
in communication with the intervention tool.
7. The system of claim 6 further comprising an upper completion
section deployable on the plurality of wired drill pipes and
communicatively coupled to the lower completion section.
8. The system of claim 3 wherein the downhole interface is directly
coupled to the wireline tool and one of the plurality of wired
drill pipes.
9. The system of claim 8 wherein the downhole interface includes
electronics providing a power interface between one of the
plurality of wired drill pipes and the wireline tool.
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 claim 10 wherein the wireline tool is an
intervention tool.
12. The system of claim 10 wherein information from the wireline
tool is transmitted to the downhole interface and then transmitted
to the wired drill pipes for transmission to the Earth's
surface.
13. The system of claim 12 wherein the wireline tool is controlled
based on an analysis of the information from the wireline tool.
14. The system of claim 11 wherein the intervention tool is
positioned in a lower completion section.
15. The system of claim 11 wherein a portion of the drill string
comprises the lower completion section.
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 claim 16 wherein the wireline tool is an
intervention tool.
18. The method of claim 16 wherein at least a portion of the
plurality of wired drill pipes comprise a lower completion
section.
19. The method of claim 18 wherein the lower completion section
includes packers or sliding sleeves.
20. The method of claim 16 wherein the characteristic of the
wellbore is a formation measurement.
Description
PRIORITY CLAIMS AND RELATED APPLICATIONS
[0001] 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.
[0002] 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.
[0003] 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.
[0004] 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.
FIELD OF THE INVENTION
[0005] 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.
BACKGROUND OF THE INVENTION
[0006] 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.
[0007] 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.
[0008] 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.
[0009] 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.
[0010] 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.
[0011] 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.
BRIEF DESCRIPTION OF THE DRAWINGS
[0012] 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.
[0013] FIG. 1 is a schematic view, partially in cross-section of
wellsite having a downhole tool deployed from a rig and into a
wellbore via a drill string having a wired drill pipe telemetry
system therein.
[0014] FIG. 2A is a schematic view of an embodiment of an uphole
interface for passing signals between a surface unit and a wired
drill pipe telemetry system.
[0015] FIG. 2B is a schematic view of an embodiment of a downhole
interface for passing signals between a surface unit and a wired
drill pipe telemetry system.
[0016] FIG. 3 is a schematic view of an embodiment of a modem
usable in the downhole interface of FIGS. 2A and 2B.
[0017] FIGS. 4A-D are schematic views of various configurations of
interfaces used in combination with wired drill pipe telemetry
systems and downhole tools.
[0018] FIGS. 5A and 5B are cross-sectional views of embodiments of
the interface of the invention.
[0019] FIGS. 6A and 6B are cross-sectional views of modularized
interfaces in accordance with embodiments of the invention.
[0020] FIGS. 6C and 6D are cross-sectional views of interfaces in
accordance with further embodiments of the invention.
[0021] FIGS. 7A-7C are schematic diagrams, in block form, of the
electronics used in embodiments of the interfaces of the
invention.
[0022] FIGS. 8 and 9 show block diagrams of a controller and modem,
respectively, used in embodiments of the invention.
[0023] FIG. 10 illustrates a wireline tool suspended within the
wellbore and in communication with the surface in an embodiment of
the invention.
DETAILED DESCRIPTION OF THE INVENTION
[0024] 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.
[0025] FIG. 1 illustrates a wellsite system 1 with which the
present invention can be utilized to advantage. In the illustrated
system, a borehole 11 is formed by rotary drilling in a manner that
is well known. Those of ordinary skill in the art given the benefit
of this disclosure will appreciate, however, that the present
invention also finds application in drilling applications other
than conventional rotary drilling (e.g., mud-motor based
directional drilling and rotary steerable systems), and is not
limited to land-based rigs.
[0026] 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.
[0027] 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.
[0028] 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.
[0029] 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.
[0030] 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.
[0031] As shown in FIG. 1, an uphole interface 120 is provided at
the uphole end of the drill string 12, a downhole interface is
provided at the downhole end of the drill string 12. A wired drill
pipe telemetry system 145 extends through the drill string 12. A
communication link 130 is schematically depicted between the uphole
interface and the surface unit 4. This configuration provides a
communication link from the surface telemetry unit 4, through
communication link 130, to uphole interface 120, through the wired
drill pipe telemetry system, to interface 140 and to downhole tool
(or BHA) 100.
[0032] 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.
[0033] As shown in FIG. 1, the uphole interface is positioned at
the uphole end of the wired drill pipe telemetry system. The uphole
interface operatively connects the wired drill pipe telemetry
system to the surface unit. As shown, a communication link is
provided between the uphole interface and the surface unit.
Optionally, in cases where the drill pipe extends above the rotary
table and to the top drive, the interface sub may, for example, be
positioned between the top drive and the wired drill pipe.
[0034] The uphole interface 120 is shown in greater detail in FIG.
2A. The uphole interface is provided with a surface modem 200, a
WDP uphole modem 202, sensors 204 and a power module 206.
Typically, the uphole interface is housed in a drill pipe
connectable to the uphole end of the drill string.
[0035] 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.
[0036] 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.
[0037] 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.
[0038] 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.
[0039] 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.
[0040] The surface modem 200 is shown in greater detail in FIG. 3.
The modem may be analog or digital. The modem includes a
transmitter 300, a receiver 302, a processor 304 and a memory unit
306. The transmitter and receiver may be in the form of an analog
or digital transceiver. The transmitter is provided to transmit
data received by the receiver from the downhole unit to the surface
unit. The transmitter may also be used to transmit commands
received from the surface unit by the receiver to the downhole
tool. Diagnostic signals may also be transmitted from the interface
sub to the downhole tool and/or surface unit. For diagnostics,
signals from the downhole tools/surface units can be looped back to
the downhole tools/surface units, respectively.
[0041] 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.
[0042] The memory unit 306 is provided to store data for future
use. Sensor or diagnostic data, for example, may be stored.
[0043] 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.
[0044] Referring now to FIG. 2B, a downhole interface 140 is
depicted. The downhole interface is positioned between the WDP
telemetry system and the downhole tool for communication
therebetween. In some cases, a separate downhole interface may not
be necessary, where the downhole tool is provided with an internal
interface. Such an internal interface is made up of existing
modems, processors, sensors and other features in the current
downhole tool.
[0045] 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.
[0046] 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.
[0047] FIG. 4 schematically depicts a variety of possible
configurations utilizing one or more interfaces. The interfaces may
be positioned at a variety of locations along the wellsite. For
example, one of the uphole interface may be positioned adjacent the
top drive, and another located further downhole. In another
example, one downhole interface may be positioned adjacent the
wired drill pipe telemetry system, and another interface positioned
further downhole along the downhole tool.
[0048] FIG. 4A shows a wired drill pipe telemetry system 445
directly connected to a downhole tool 410. An uphole interface 422
is positioned above the wired drill pipe telemetry system. A
downhole interface 440 is integral to the downhole tool 410. In
this situation, the downhole interface may be formed from existing
portions of the downhole tool, such as processors, modems and other
devices that form portions of the components of the downhole
tool.
[0049] FIG. 4B depicts multiple wired drill pipe telemetry systems
445, each having its own downhole interface 450. An uphole
interface 422 is provided at an uphole end of the upper most wired
drill pipe telemetry system. The downhole interfaces 450 can
communicate simultaneously or independently with the downhole tool
410.
[0050] FIG. 4C depicts multiple downhole tools, each having its own
downhole interface 450. An uphole interface 422 is provided at an
uphole end of the wired drill pipe telemetry system. FIG. 4D
depicts a wired drill pipe telemetry system having multiple uphole
interfaces 422 and multiple downhole interfaces 450.
[0051] FIG. 5A depicts an example of an interface 500 for use
between a wired drill pipe system, such as the wired drill pipe
system 145 of FIG. 1 and a downhole tool or bottom hole assembly,
such as the BHA 100 of FIG. 1. The interface 500 includes a housing
502, a WDP connector 524, a downhole connector 526 and electronics
550. As shown, the electronics are positioned on an inner surface
of the drill collar to permit the flow of mud therethrough as
indicated by the arrows. The electronics are preferably removably
loaded into the drill collar and mounted against a shoulder
527.
[0052] 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.
[0053] 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 FIGS. 2A, 2B and 3. FIGS. 7A-9 illustrate
additional configurations for the electronics as will be described
further below.
[0054] As shown in FIG. 5A, additional features, such as a read out
port 525 may also be provided. The read out port provides access to
the electronics. For example, when the tool is retrieved to the
surface, a surface unit may be plugged into the readout port to
retrieve data, insert commands, terminate power or perform other
procedures.
[0055] FIG. 5B depicts an interface 500a with a partially annular
and partially mandrel style configuration. Interface 500a is
essentially the same as FIG. 5A, except that a portion of the
electronics is positioned in a mandrel layout. In other words, a
portion of the electronics 550a are positioned along the inner
surface of housing 502 as shown in FIG. 5A, and another portion of
the electronics 550b are positioned in a mandrel configuration
within the housing. Centralizers 552 are positioned along the inner
surface of the housing to support the electronics 550b, and have
apertures therethrough to permit the passage of drilling mud as
indicated by the arrows.
[0056] FIGS. 6A-D depict various configurations of a modular
interface for use between a wired drill pipe system, such as the
wired drill pipe system 145 of FIG. 1 and a downhole tool or bottom
hole assembly, such as the BHA 100 of FIG. 1. As shown in FIG. 6A,
the modular interface 600 includes a housing 602, a WDP connector
624, downhole connectors 626a, 626b, and electronics 650a, 650b. As
shown, the electronics are positioned on an inner surface of the
drill collar to permit the flow of mud therethrough as indicated by
the arrows. The electronics are preferably removably loaded into
the drill collar and mounted on along an inner surface thereof.
[0057] The housing may be the same as in FIG. 5A. As shown in FIG.
6A, uphole end 631 is a box end, and downhole end 633 is a pin end
with threadable connections for operatively connecting to their
respective tools.
[0058] 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 650a, 650b 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.
[0059] One or more connectors, such as link 662, may be used to
operatively connect the electronics 650a and 650b. Links 670a and
670b are provided to operatively connect the electronics 650a to
WDP connector 624 and electronics 650b to downhole connector 626b,
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.
[0060] The WDP connector 624 and the downhole connector 626a may be
the same as the connectors 524, 526, respectively. Optionally, an
additional or alternative downhole connector 626b may be used, such
as an inductive or conductive connector operatively connectable to
the downhole tool. The electronics 650a, 650b are used to pass
signals between the WDP system and the downhole tool. The
electronics 650a and 650b are depicted as having a WDP modem 620
and a downhole modem 622, respectively to enable communication
therethrough. Connectors, such as 624, 626a and 626b may be
positioned at various locations within the interface, so long as an
operative connection is provided.
[0061] Additional electronics may also be included, such as the
electronics shown in FIGS. 2A, 2B and 3. FIGS. 7A-9 describe
additional configurations for the electronics as will be described
further below. As shown in FIG. 6A, read out ports 625a, b may also
be provided with read out circuitry positioned therein. For
example, such read out circuitry may include sensors and other
electronics, such as those shown in FIGS. 7A-9 and described
further herein. The read out ports 625a, 625b may be the same as
the read out port 525 of FIG. 5A, except that circuitry may be
provided therein to facilitate connections and signal
transfers.
[0062] As shown in FIG. 6A, one or more additional components 672
may be positioned in the interface to perform a variety of
additional functions. For example, the component may be used to
perform a variety of downhole operations, such as downhole sensing
(i.e. pressure), power generation, telemetry, memory or other
operations.
[0063] FIG. 6B shows an alternate configuration of a modular
interface 600a is the same as the modular interface 600a of FIG.
6A, except that additional electronics 650c and 650d are provided.
As shown electronics 650c are additional electronics positioned in
an annular position along the inner surface of the housing 602
adjacent the electronics 650a. Electronics 650d are supported on
centralizers 652 in a mandrel position within the housing. In this
configuration, the modular connection may be separate along
connection 660 such that a first portion of the interface contains
electronics 650a and 650c, and a second portion contains
electronics 650b and 650d. Additional connections 660 may be
provided to permit additional separations, for example for threaded
end 631 with coupler 624 and threaded end 633 with downhole
connector 626b.
[0064] FIG. 6C shows an alternate modular interface 600b. In this
configuration, electronics 650a are positioned along the inner
surface, and electronics 650e is positioned on an inner surface of
the housing adjacent electronics 650a. Electronics 650a is provided
with WDP modem 620, and electronics 650e is provided with downhole
modem 622. Preferably, electronics 650e are removably positioned
within the drill collar. In this manner, the electronics 650e may
be separated from the interface for separate maintenance,
installation, etc.
[0065] As shown in FIG. 6C, the housing has a first box end 631,
and a pin end 633a. As described above, the ends may be box and/or
pin or other connections capable of operatively connecting the
interface with the drill string and/or downhole tool.
[0066] FIG. 6D shows an alternate modular interface 600c. The
modular interface 600c may be the same as the modular interface
600b of FIG. 6C, except that the electronics 650e is replaced with
electronics 650f in a mandrel configuration. Downhole modem 622 is
positioned in electronics 650f for communication with the downhole
tool.
[0067] Centralizers 652a, 652b are provided to support the
electronics 650f in the housing. Centralizer 652a may be, for
example, supports positioned about the electronics. Centralizer
652b may be, for example, a ring or spider used to support the
electronics.
[0068] While the configurations shown in FIGS. 5A-6D depict
specific arrangements of electronics, connectors and other devices
within a housing, it will be appreciated that these arrangements
may be varied. For example, WDP connectors and modems may be
positioned in various locations about the housing.
[0069] FIGS. 7A-C are schematic diagrams depicting a detailed view
of the electronics 750 usable with the interfaces provided herein.
As shown, the electronics include a WDP modem 720, a downhole modem
722 and power module 781. As shown, power may be provided
internally using power module 781 and/or battery 771 and/or
external power source 772. Additional electronics may also be
provided, such as diagnostics 773, controller 774, sensors 775,
GPS/real time clock 776 and read out port (ROP) 725.
[0070] 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 FIG. 2B.
The GPS/real time clock may be used, for example, to provide a time
stamp for the data acquired from the sensor and time
synchronization. The read out port may be the same as the read out
port 625 described herein.
[0071] FIG. 7B depicts an alternate configuration for the
electronics 750a. In this configuration, the electronics 750 of
FIG. 7A are separated into a WDP portion 782, and a downhole
portion 780 with a connector 762 therebetween. As shown, the
electronics 780 are the same as the electronics 750 of FIG. 7A,
except that the WDP modem 720 has been moved to the WDP portion
782, and a signal/power interface 778 is provided to operatively
communicate with the WDP portion 782.
[0072] The WDP portion 782 is provided with the WDP modem 720 and a
signal/power interface 778b that communicates with signal power
interface 778a 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.
[0073] FIG. 7C depicts another configuration of electronics 750b.
This configuration is the same as the electronics 750a of FIG. 7B,
except that the WDP portion 782a is provided with additional
electronics. The WDP portion 782a contains the WDP modem 720 and
the signal power interface 778b (as with previous WDP portion 782
of FIG. 7B), plus power module 781, battery 771, GPS/real time
clock 776, ROP 725, sensors 775, controller 774, diagnostics 773 an
external power 772. This configuration shows that a variety of
electronics may be used with the one or more portions of the
electronics. While two portions are depicted, multiple portions
containing various portions of the electronics may be provided.
Connectors may be needed to join the respective electronics.
[0074] FIGS. 8 and 9 show an alternate configuration of the surface
modem 200 of FIG. 3, split into separate portions. FIG. 8 is a
detailed view of a controller 774. The controller may be provided
with a processor 892, memory 894, Application Specific Integrated
Circuit (ASIC)/Field Programmable Device (FPD) 893 and other
circuitry.
[0075] FIG. 9 is a detailed view of downhole modem 772. The same
configuration may be used for WDP modem 720. The modem may include,
for example, a transmitter and receiver (or transceiver) 995. In
cases where analog is used, the modem may also be provided with a
filter 996, an amplifier 997, a gain control 998, a modulator 999,
a demodulator 989 and a data converter 988.
[0076] The interfaces as shown in FIGS. 5A-6D may be positioned
about a WDP system and/or downhole tool as shown in FIGS. 4A-4D.
For example, the interfaces of FIGS. 5A-6D may be configured as
surface interfaces, such as the interfaces 422 of FIGS. 4A-4D,
integral interface 440 of FIG. 4A and/or downhole interfaces 450 of
FIGS. 4B-4D. The interfaces as described herein may also be
provided with one or more repeaters to amplify and/or reshape the
signal. Repeaters and other devices, such as the modem depicted in
FIG. 9, may be used to improve the signal as it is passed through
the wellbore.
[0077] 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.
[0078] FIG. 10 illustrates an embodiment of a downhole tool 1500
that may be used with a downhole interface, such as the interfaces
140, 440, 450, 500, 500a, 600 and 600a. The downhole tool 1500 may
be a tool typically conveyed on a wireline ("wireline tool"), such
as an intervention tool. The downhole tool 1500 may be deployed on
drill pipe. With drill pipe, however, it is difficult to provide an
electric cable along the drill pipe due to the joints of pipe. To
address this, the downhole tool 1500 may be used with the wired
drill pipe telemetry system 445 disclosed herein. The wired drill
pipe telemetry system 445 may provide communication with the
downhole interface 140, 440, 450, 500, 500a, 600 and 600a to
communicate to the surface. For example, the downhole tool 1500 may
be inductively coupled by the inductive coupler 1180 and/or the
inductive coupler 1504 to the downhole interface 140, 440, 450,
500, 500a, 600 and 600a.
[0079] 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.
[0080] FIG. 10 also illustrates a lower completion section 1020
that may include components that can be manipulated by the downhole
tool 1500, such as sliding sleeves that can be opened or closed,
packers that can be set or unset, and so forth. In an embodiment,
the lower completion section 1020 includes a packer 1200 (e.g.
gravel pack packer) that when set seals against casing. The packer
1200 may isolate an annulus region under the packer 1200.
[0081] 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.
[0082] 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.
[0083] 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.
* * * * *