U.S. patent application number 11/217185 was filed with the patent office on 2007-03-01 for apparatus and method for evaluating a formation.
This patent application is currently assigned to Baker Hughes Incorporated. Invention is credited to Daniel Georgi.
Application Number | 20070044959 11/217185 |
Document ID | / |
Family ID | 37802427 |
Filed Date | 2007-03-01 |
United States Patent
Application |
20070044959 |
Kind Code |
A1 |
Georgi; Daniel |
March 1, 2007 |
Apparatus and method for evaluating a formation
Abstract
An apparatus and method for evaluating a formation is presented.
The apparatus comprises a tubular string deployed into a wellbore
penetrating the formation, where the tubular string has a
longitudinal flow passage therethrough. A flow sub in the tubular
string provides fluid communication between the longitudinal flow
passage in the tubular string and an annulus between the tubular
string and a wall of the wellbore. A wireline tool is attached
proximate a bottom end of the flow sub. A telemetry module
proximate the flow sub provides communication between the wireline
tool and a surface system, without the use of a wireline to the
surface.
Inventors: |
Georgi; Daniel; (Houston,
TX) |
Correspondence
Address: |
MADAN, MOSSMAN & SRIRAM, P.C.
2603 AUGUSTA
SUITE 700
HOUSTON
TX
77057
US
|
Assignee: |
Baker Hughes Incorporated
Houston
TX
|
Family ID: |
37802427 |
Appl. No.: |
11/217185 |
Filed: |
September 1, 2005 |
Current U.S.
Class: |
166/250.01 ;
175/40 |
Current CPC
Class: |
E21B 49/10 20130101;
E21B 23/14 20130101 |
Class at
Publication: |
166/250.01 ;
175/040 |
International
Class: |
E21B 47/00 20060101
E21B047/00 |
Claims
1. An apparatus for evaluating a formation, comprising: a tubular
string deployed into a wellbore penetrating the formation, the
tubular string having a longitudinal flow passage therethrough; a
flow sub in the tubular string, said flow sub providing fluid
communication between the longitudinal flow passage in the tubular
string and an annulus between the tubular string and a wall of the
wellbore; a wireline tool attached proximate a bottom end of the
flow sub; and a telemetry module proximate the flow sub providing
communication between the wireline tool and a surface system,
without the use of a wireline to the surface.
2. The apparatus of claim 1, further comprising a downhole power
source.
3. The apparatus of claim 2, wherein the downhole power source
comprises a turbine-alternator disposed in a fluid flowing in the
axial flow passage and generating electrical power therefrom.
4. The apparatus of claim 1, wherein the tubular string comprises
drill pipe.
5. The apparatus of claim 1, wherein the wireline tool comprises at
least one of: a formation test tool; a resistivity tool, a nuclear
tool, and a nuclear magnetic resonance tool.
6. The apparatus of claim 1, wherein the telemetry module comprises
a mud pulser transmitting encoded pulses in the flowing fluid that
are detected by the surface system.
7. The apparatus of claim 1, wherein the surface system comprises a
surface pulser transmitting a downlink signal to the telemetry
module.
8. The apparatus of claim 7, wherein the downlink signal comprises
commands for operation of at least one of the wireline tool and the
telemetry module.
9. The apparatus of claim 1, wherein the telemetry module comprises
a controller having a processor and a memory.
10. The apparatus of claim 9, wherein a signal from the wireline
tool is stored in the memory in the telemetry module.
11. The apparatus of claim 1, wherein the wellbore comprises a
highly deviated wellbore.
12. A method for evaluating a formation, comprising: deploying a
tubular string into a wellbore penetrating the formation; providing
fluid communication between a longitudinal flow passage in the
tubular string and an annulus between the tubular string and a wall
of the wellbore using a flow sub attached to the tubular string;
measuring a parameter of interest with a wireline tool attached to
the tubular string below the flow sub; and communicating between
the wireline tool and a surface system without the use of a
wireline.
13. The method of claim 12, further comprising supplying electrical
power proximate the flow sub.
14. The method of claim 12, wherein the tubular string comprises
drill pipe.
15. The method of claim 12, wherein the wireline tool is chosen
from the group consisting of: a formation test tool; a resistivity
tool, a nuclear tool, and a nuclear magnetic resonance tool.
16. The method of claim 12, wherein the step of communicating
between the wireline tool and a surface system without the use of a
wireline comprises generating encoded mud pulses in a fluid and
detecting the encoded pulses at the surface.
17. The method of claim 12, wherein the step of communicating
between the wireline tool and a surface system without the use of a
wireline comprises transmitting a downlink signal from the surface
system to a telemetry module proximate the wireline tool.
18. The method of claim 17, wherein the downlink signal comprises
commands for operation of at least one of the wireline tool and the
telemetry module.
19. The method of claim 17, wherein the telemetry module comprises
a controller having a processor and a memory.
20. The method of claim 12, wherein a signal from the wireline tool
is stored in the memory in the telemetry module.
21. The method of claim 13, wherein the step of supplying
electrical power proximate the flow sub comprises inserting a
turbine-alternator disposed in a flowing fluid downhole and
generating electrical power therefrom.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] Not applicable
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT
[0002] Not applicable
BACKGROUND OF THE INVENTION
[0003] 1. Field of the Invention
[0004] This invention relates generally to logging of subsurface
reservoirs and more particularly to pipe conveyed logging.
[0005] 2. Description of the Related Art
[0006] Ordinarily, gravity is used to pull logging tools along and
into a well borehole for conducting logging operations. When a well
is highly deviated from vertical, the force exerted by gravity may
not be sufficient to draw the logging tool through a deviated
portion of the well. Many oil wells are deviated. For example, an
offshore platform commonly has many wells drilled from the platform
into various portions of a targeted formation that surrounds the
location of the platform. While some of the wells might be
approximately vertical, most of the wells extending from the
platform will deviate at various angles into the formations of
interest and some may involve deviations up to, or above,
horizontal. Gravity conveyed logging tools supported on wirelines
lose the effect of gravity for forcing the tool through the hole
and simply do not have sufficient motive force to traverse the
deviated hole to the zone to be logged. In many instances, the
logging tool must be pushed through the deviated well to the zone
of interest to ensure that the logging tool is located at the
requisite location in the deviated hole. It is desirable therefore
that the logging tool be fixed to the end of a string of
sufficiently stiff pipe to log along the deviated well at the zone
of interest. In many cases, this requires using large pipe, such as
drill pipe, to have the stiffness required for logging these
sections.
[0007] A known method for logging highly deviated wells, disclosed
in U.S. Pat. No. 4,457,370, to Wittrisch, consists of the following
steps. A well logging tool is secured to the bottom of a section of
drill pipe, inside a protective sleeve, and the tool is lowered
into the well as additional sections of pipe are assembled. An
electrical connector attached to the end of a wireline cable is
then inserted into the drill pipe, the cable is passed through a
side entry sub mounted on top of the drill string and the connector
is pumped down through the drill pipe into engagement with a mating
connector attached to the logging tool to effect connection of the
tool to the cable and therefore the surface control equipment. Then
other sections of drill pipe are added, the portion of the cable
above the side entry sub running outside the drill pipe, until the
tool reaches the bottom of the section to be logged. Then the
logging operation is performed as the drill pipe is moved through
the desired section.
[0008] The running of the cable and the additional care and
complexity required to protect the cable during pipe movement
increase the time required to obtain a log. In addition the making
of a wet connect is commonly prone to failure requiring additional
time and effort to correct.
[0009] There is a demonstrated need for providing an apparatus and
method for logging a highly deviated wellbore that does not require
the running of a wireline cable or the making of a wet connect.
SUMMARY OF THE INVENTION
[0010] In one aspect of the present invention, an apparatus for
evaluating a formation comprises a tubular string deployed into a
wellbore penetrating the formation, where the tubular string has a
longitudinal flow passage therethrough. A flow sub in the tubular
string provides fluid communication between the longitudinal flow
passage in the tubular string and an annulus between the tubular
string and a wall of the wellbore. A wireline tool is attached
proximate a bottom end of the flow sub. A telemetry module
proximate the flow sub provides communication between the wireline
tool and a surface system, without the use of a wireline to the
surface.
[0011] In another aspect, a method for evaluating a formation
comprises deploying a tubular string into a wellbore penetrating
the formation. Fluid communication is provided between a
longitudinal flow passage in the tubular string and an annulus
between the tubular string and a wall of the wellbore using a flow
sub attached to the tubular string. A parameter of interest is
measured with a wireline tool attached to the tubular string below
the flow sub. Communication between the wireline tool and a surface
system is accomplished without the use of a wireline.
BRIEF DESCRIPTION OF THE DRAWINGS
[0012] For detailed understanding of the present invention,
references should be made to the following detailed description of
the embodiments, taken in conjunction with the accompanying
drawings, in which like elements have been given like numerals,
wherein:
[0013] FIG. 1 is a drawing of a logging system according to at
least one embodiment of the present invention;
[0014] FIG. 2 is a blown up portion of bottom assembly 30 of FIG.
1;
[0015] FIG. 3 is a drawing showing an example of multiple sample
tanks in a formation test tool; and
[0016] FIG. 4 is a block diagram of the interrelationship of
several components of the present invention.
DESCRIPTION OF EMBODIMENTS
[0017] FIGS. 1 and 2 show an exemplary embodiment of the present
invention. Rig 5 supports a string 13 of jointed pipe in borehole
15, also called a wellbore, that extends through formation 20. As
shown, borehole 15 is highly deviated and may include substantially
horizontal sections. As used herein, highly deviated refers to
wellbores that are deviated from vertical by about 70 degrees, or
more. String 13 is made up of pipe sections 10 joined together at
threaded connections 12. The pipe may be drill pipe of the type
known in the art. String 13 extends in borehole 13 into a
subterranean formation 20. Bottom assembly 30 is attached to the
bottom of string 15 and comprises telemetry module 35, and flow sub
31. Attached below flow sub 31 are wireline logging tools 32A and
32B. As one skilled in the art will appreciate, and as used herein,
a wireline tool is intended to be a tool designed to be commonly
deployed into and out of the wellbore on an electrical wireline
cable, and is distinguished from tools designed for use during
measurement while drilling (MWD) operations. Commonly, wireline
tools are not designed to survive the shock, vibration, and torsion
of the drilling operation, as required by MWD tools. It is
understood, in the context of the present invention, that minor
mechanical modifications to a wireline tool to mechanically
interface the tool for the present invention, do not alter the
nature of the tool as a wireline tool.
[0018] As shown, tool 32A is a formation test tool. Logging tool
32B comprises a logging tool that may include, but is not limited
to, at least one of: a nuclear magnetic resonance logging tool
(NMR); a resistivity tool; and a nuclear density tool. Such tools
are used to determine various parameters of interest of the
formation including, but not limited to: formation resistivity,
formation porosity, and formation permeability. Multiple wireline
logging tools may be connected together in a logging string below
flow sub 31. It should be noted that there is no significance to
the specific location of particular logging tools in the logging
string. For example, if multiple wireline tools are connected below
flow sub 31, formation test tool 32A may be located at any location
in the logging string.
[0019] Surface pump 3 pumps fluid 38 through string 13 and down
through bottom assembly 30. Fluid 38 exits through flow port 50 in
flow sub 31 into the annulus between the string 13 and the wall 14
of borehole 15 where it returns to the surface. While only one flow
port 50 is shown, additional ports are located around the
circumference of flow sub 31. Energy conductor 51 is disposed
within the body of flow sub 31 and enables power and information to
be communicated between wireline logging tools 32A and 32B and
pulser 53, described below. Alternatively, multiple conductors may
be routed in similar fashion.
[0020] Fluid 38 provides flow energy to power turbine/alternator 52
(shown in cutaway inside telemetry module 35, and in FIG. 2) to
generate sufficient electrical power to operate the downhole
logging tools and other downhole devices described herein. Such
turbine/alternators are known in the art and are not discussed, in
detail, here.
[0021] Telemetry module 35 also contains oscillating shear valve
pulser 53, see FIG. 2, wherein rotor 60 oscillates proximate stator
61 to restrict a portion of flow of fluid 38 thereby generating
pressure signals 41 that propagate to the surface through fluid 38.
Pressure signals 38 are detected by transducer 7 that is in fluid
communication with the output flow line of pump 3. Transducer 7 is
commonly a pressure transducer of a kind known in the art.
Alternatively, transducer 7 may be a flow transducer in line with
the pump output detecting changes in flow related to pressure
signals 41. For additional details of the operation of oscillating
shear valve pulser 53, see U.S. Pat. No. 6,626,252, assigned to the
assignee of this application and which is incorporated herein by
reference. While described herein as used with a shear valve
pulser, any suitable downhole mud pulser is intended to be within
the scope of the present invention. Such pulsers include, but are
not limited to: positive pulsers, negative pulsers, and continuous,
also called siren, pulsers. In addition, surface located downlink
pulser 4 transmits pulses 42 from the surface controller 8 to the
downhole system. Pulses 42 contain instructions and status
information used for operating the downhole system.
[0022] Alternatively, other types of transmission schemes known in
the art, that do not employ a wireline connection between the
surface and the wireline tool, are intended to be within the scope
of the present invention. These include, but are not limited to:
acoustic transmission through the pipe wall and electromagnetic
telemetry.
[0023] In one embodiment, wireline tool 32A is a formation test
tool such as those described in U.S. Pat. Nos. 5,303,775;
5,377,755; 5,549,159; 5,587,525; 6,420,869; 6,683,681; 6,798,518;
and published application US 2004/0035199 A1, each of which is
assigned to the assignee of this application, and each of which is
incorporated herein by reference. Anchors 36 and sample probe 34
are extendable from the body of tool 32A to force sample probe 34
into contact with wellbore wall 14 and hence into fluid
communication with formation 20. In one embodiment, as illustrated
in FIG. 3, the tool 32A of FIG. 1 is shown to incorporate a
bi-directional piston pump mechanism shown generally at 124 which
is illustrated schematically. Within the tool 32A is also provided
at least one and preferably a plurality of sample tanks such as
exemplary tanks 126 and 128, which may be of identical construction
if desired. The piston pump mechanism 124 defines a pair of opposed
pumping chambers 162 and 164 which are disposed in fluid
communication with the respective sample tanks via supply conduits
134 and 136. Discharge from the respective pump chambers to the
supply conduit of a selected sample tank 126 or 128 is controlled
by electrically energized three-way valves 127 and 129 or by any
other suitable control valve arrangement enabling selective filling
of the sample tanks. The respective pumping chambers are also shown
to have the capability of fluid communication with the subsurface
formation of interest via pump chamber supply passages 138 and 140
which are defined by the sample probe 34 of FIG. 1 and which are
controlled by appropriate valving. The supply passages 138 and 140
may be provided with check valves 139 and 141 to permit
overpressure of the fluid being pumped from the chambers 162 and
164 if desired. While described with two sample tanks, additional
sample tanks may be added as desired. Additional details of the
operation and design of tool 32A are contained in the incorporated
references. Parameters of interest of the sampled fluid and the
formation may be determined with sensors such as, for example,
optical sensors, density sensors, pressure sensors, and temperature
sensors incorporated in tool 32A. The parameters include, but are
not limited to, formation pressure, sample fluid refractive index,
sample fluid bubble-point, sample fluid density, sample fluid
resistivity, and sample fluid composition.
[0024] In one embodiment, see block diagram in FIG. 4, wireline
tools 32A-D are substantially unmodified for use in the present
invention. As such, the power, commands, and data transmission to
and from wireline tools 32A-D are substantially the same as if the
tools were connected by a conventional wireline to the surface.
This capability allows use of a variety of off-the-shelf logging
tools in the present invention. Downhole controller 405 contains
suitable circuitry in interface module 406 to emulate the
appropriate functions necessary to operate and control wireline
tools 32A-D. Controller 405 also comprises a processor 407 and
memory 408. At least a portion of memory 408 contains programmed
instructions for use by interface module 406 in the control of the
operation of wireline tools 32A-D. Additional circuitry (not
separately shown) is adapted to receive power form
turbine-alternator 52 and appropriately distribute the power to the
downhole components. Additional circuitry and instructions stored
in downhole controller 405 are used to process the measurement data
received form wireline tools 32A-D and to format this information
for transmission by the mud pulse system to the surface. In
addition, because the volume of data collected by the wireline
tools 32A-D is commonly orders of magnitude greater than the
capacity of the telemetry channel 401, when using mud pulse, the
measurement data or suitable subsets thereof may be stored in
memory 408 for later retrieval when the tools are returned to the
surface. Programmed instructions resident in controller 405 are
used to determine the appropriate transmission and storage
protocols.
[0025] In one embodiment, surface system 400 contains surface
controller 8 that sends commands via downlink pulser 4 to command
initiation of various downhole functions, such as, for example
performing a formation test. The commands, encoded as pulses 42 are
received by a suitable sensor in telemetry module 35, such as for
example, a pressure sensor (not separately shown). Once the
commands are received and interpreted, downhole controller 405
assumes substantially autonomous control of the formation test.
This may include data acquisition and interpretation to determine
that a suitable result is obtained. Instructions and decision rules
programmed into controller 405 are used to control this operation.
Other downlink commands may, for example, cause changes in the
encoding and pulsing format to enhance detection at the
surface.
[0026] While described herein as a system used in a highly deviated
wellbore, it is intended that the invention described herein is
also to be used for deploying heavy wireline tools, or heavy
strings of tools, that may be too heavy to be safely conveyed into
and out of wellbores that are not highly deviated, including
vertical wellbores.
[0027] The foregoing description is directed to particular
embodiments of the present invention for the purpose of
illustration and explanation. It will be apparent, however, to one
skilled in the art that many modifications and changes to the
embodiment set forth above are possible. It is intended that the
following claims be interpreted to embrace all such modifications
and changes.
* * * * *