US20070044959A1 - Apparatus and method for evaluating a formation - Google Patents
Apparatus and method for evaluating a formation Download PDFInfo
- Publication number
- US20070044959A1 US20070044959A1 US11/217,185 US21718505A US2007044959A1 US 20070044959 A1 US20070044959 A1 US 20070044959A1 US 21718505 A US21718505 A US 21718505A US 2007044959 A1 US2007044959 A1 US 2007044959A1
- Authority
- US
- United States
- Prior art keywords
- tool
- wireline
- tubular string
- telemetry module
- formation
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 31
- 238000000034 method Methods 0.000 title claims abstract description 16
- 239000012530 fluid Substances 0.000 claims abstract description 25
- 238000004891 communication Methods 0.000 claims abstract description 13
- 230000000149 penetrating effect Effects 0.000 claims abstract description 5
- 238000012360 testing method Methods 0.000 claims description 8
- 238000005481 NMR spectroscopy Methods 0.000 claims description 4
- 238000005755 formation reaction Methods 0.000 description 22
- 239000000523 sample Substances 0.000 description 18
- 230000005540 biological transmission Effects 0.000 description 5
- 230000005484 gravity Effects 0.000 description 4
- 238000005259 measurement Methods 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 239000004020 conductor Substances 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000006870 function Effects 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000010276 construction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- 230000013011 mating Effects 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000001681 protective effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B23/00—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells
- E21B23/14—Apparatus for displacing, setting, locking, releasing, or removing tools, packers or the like in the boreholes or wells for displacing a cable or cable-operated tool, e.g. for logging or perforating operations in deviated wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/10—Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
Definitions
- This invention relates generally to logging of subsurface reservoirs and more particularly to pipe conveyed logging.
- gravity is used to pull logging tools along and into a well borehole for conducting logging operations.
- 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.
- 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.
- 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.
- a known method for logging highly deviated wells 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.
- 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.
- the logging operation is performed as the drill pipe is moved through the desired section.
- 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.
- 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.
- FIG. 1 is a drawing of a logging system according to at least one embodiment of the present invention
- FIG. 2 is a blown up portion of bottom assembly 30 of FIG. 1 ;
- FIG. 3 is a drawing showing an example of multiple sample tanks in a formation test tool.
- FIG. 4 is a block diagram of the interrelationship of several components of the present invention.
- 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 .
- borehole 15 is highly deviated and may include substantially horizontal sections.
- 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 .
- wireline logging tools 32 A and 32 B Attached below flow sub 31 are wireline logging tools 32 A and 32 B.
- 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.
- tool 32 A is a formation test tool.
- Logging tool 32 B 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.
- NMR nuclear magnetic resonance logging tool
- resistivity tool e.g., a resistivity tool
- nuclear density tool e.g., 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 32 A may be located at any location in the logging string.
- Fluid 38 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 32 A and 32 B and pulser 53 , described below. Alternatively, multiple conductors may be routed in similar fashion.
- 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.
- turbine/alternator 52 shown in cutaway inside telemetry module 35 , and in FIG. 2
- Such turbine/alternators are known in the art and are not discussed, in detail, here.
- 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.
- transducer 7 may be a flow transducer in line with the pump output detecting changes in flow related to pressure signals 41 .
- oscillating shear valve pulser 53 see U.S. Pat. No.
- 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.
- 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.
- wireline tool 32 A 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 32 A to force sample probe 34 into contact with wellbore wall 14 and hence into fluid communication with formation 20 .
- FIG. 1 is shown to incorporate a bi-directional piston pump mechanism shown generally at 124 which is illustrated schematically.
- a bi-directional piston pump mechanism shown generally at 124 which is illustrated schematically.
- Within the tool 32 A 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 32 A 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 32 A. 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.
- wireline tools 32 A-D are substantially unmodified for use in the present invention.
- the power, commands, and data transmission to and from wireline tools 32 A-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 32 A-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 32 A-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 32 A-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 32 A-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.
- 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).
- a suitable sensor in telemetry module 35 such as for example, a pressure sensor (not separately shown).
- 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.
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.
Description
- Not applicable
- Not applicable
- 1. Field of the Invention
- This invention relates generally to logging of subsurface reservoirs and more particularly to pipe conveyed logging.
- 2. Description of the Related Art
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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:
-
FIG. 1 is a drawing of a logging system according to at least one embodiment of the present invention; -
FIG. 2 is a blown up portion ofbottom assembly 30 ofFIG. 1 ; -
FIG. 3 is a drawing showing an example of multiple sample tanks in a formation test tool; and -
FIG. 4 is a block diagram of the interrelationship of several components of the present invention. -
FIGS. 1 and 2 show an exemplary embodiment of the present invention.Rig 5 supports astring 13 of jointed pipe inborehole 15, also called a wellbore, that extends throughformation 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 ofpipe sections 10 joined together at threadedconnections 12. The pipe may be drill pipe of the type known in the art.String 13 extends inborehole 13 into asubterranean formation 20.Bottom assembly 30 is attached to the bottom ofstring 15 and comprisestelemetry module 35, andflow sub 31. Attached belowflow sub 31 arewireline logging tools - 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 belowflow 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 belowflow sub 31,formation test tool 32A may be located at any location in the logging string. -
Surface pump 3pumps fluid 38 throughstring 13 and down throughbottom assembly 30.Fluid 38 exits throughflow port 50 inflow sub 31 into the annulus between thestring 13 and thewall 14 ofborehole 15 where it returns to the surface. While only oneflow port 50 is shown, additional ports are located around the circumference offlow sub 31.Energy conductor 51 is disposed within the body offlow sub 31 and enables power and information to be communicated betweenwireline logging tools pulser 53, described below. Alternatively, multiple conductors may be routed in similar fashion. -
Fluid 38 provides flow energy to power turbine/alternator 52 (shown in cutaway insidetelemetry module 35, and inFIG. 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. -
Telemetry module 35 also contains oscillatingshear valve pulser 53, seeFIG. 2 , whereinrotor 60 oscillatesproximate stator 61 to restrict a portion of flow offluid 38 thereby generating pressure signals 41 that propagate to the surface throughfluid 38. Pressure signals 38 are detected by transducer 7 that is in fluid communication with the output flow line ofpump 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 oscillatingshear 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 locateddownlink pulser 4 transmitspulses 42 from thesurface controller 8 to the downhole system.Pulses 42 contain instructions and status information used for operating the downhole system. - 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.
- 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 andsample probe 34 are extendable from the body oftool 32A to forcesample probe 34 into contact withwellbore wall 14 and hence into fluid communication withformation 20. In one embodiment, as illustrated inFIG. 3 , thetool 32A ofFIG. 1 is shown to incorporate a bi-directional piston pump mechanism shown generally at 124 which is illustrated schematically. Within thetool 32A is also provided at least one and preferably a plurality of sample tanks such asexemplary tanks piston pump mechanism 124 defines a pair of opposed pumpingchambers supply conduits sample tank 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 pumpchamber supply passages sample probe 34 ofFIG. 1 and which are controlled by appropriate valving. Thesupply passages check valves 139 and 141 to permit overpressure of the fluid being pumped from thechambers 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 intool 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. - 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 fromwireline 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 ininterface module 406 to emulate the appropriate functions necessary to operate and controlwireline 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 byinterface module 406 in the control of the operation ofwireline 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 indownhole controller 405 are used to process the measurement data receivedform 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 thewireline tools 32A-D is commonly orders of magnitude greater than the capacity of thetelemetry 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 incontroller 405 are used to determine the appropriate transmission and storage protocols. - In one embodiment,
surface system 400 containssurface controller 8 that sends commands viadownlink pulser 4 to command initiation of various downhole functions, such as, for example performing a formation test. The commands, encoded aspulses 42 are received by a suitable sensor intelemetry 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 intocontroller 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. - 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.
- 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.
Claims (21)
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.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/217,185 US20070044959A1 (en) | 2005-09-01 | 2005-09-01 | Apparatus and method for evaluating a formation |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/217,185 US20070044959A1 (en) | 2005-09-01 | 2005-09-01 | Apparatus and method for evaluating a formation |
Publications (1)
Publication Number | Publication Date |
---|---|
US20070044959A1 true US20070044959A1 (en) | 2007-03-01 |
Family
ID=37802427
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/217,185 Abandoned US20070044959A1 (en) | 2005-09-01 | 2005-09-01 | Apparatus and method for evaluating a formation |
Country Status (1)
Country | Link |
---|---|
US (1) | US20070044959A1 (en) |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20090242274A1 (en) * | 2004-06-18 | 2009-10-01 | Schlumberger Technology Corporation | Apparatus for measuring streaming potentials and determining earth formation characteristics |
US20100071910A1 (en) * | 2008-09-25 | 2010-03-25 | Nicholas Ellson | Method and system for using wellbore instruments with a wired pipe string |
US20100300685A1 (en) * | 2009-06-01 | 2010-12-02 | Del Campo Christopher S | Method and system for using wireline configurable wellbore instruments with a wired pipe string |
US20110164999A1 (en) * | 2010-01-04 | 2011-07-07 | Dale Meek | Power pumping system and method for a downhole tool |
US10385682B2 (en) | 2016-08-15 | 2019-08-20 | Baker Hughes, A Ge Company, Llc | Pipe conveyed logging and drill pipe communication integration system and method |
Citations (78)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3315224A (en) * | 1964-09-01 | 1967-04-18 | Exxon Production Research Co | Remote control system for borehole logging devices |
US4303994A (en) * | 1979-04-12 | 1981-12-01 | Schlumberger Technology Corporation | System and method for monitoring drill string characteristics during drilling |
US4457370A (en) * | 1981-03-13 | 1984-07-03 | Institut Francais Du Petrole | Method and device for effecting, by means of specialized tools, such operations as measurements in highly inclined to the vertical or horizontal well portions |
US4532614A (en) * | 1981-06-01 | 1985-07-30 | Peppers James M | Wall bore electrical generator |
US4597440A (en) * | 1985-04-04 | 1986-07-01 | Schlumberger Technology Corporation | Method and apparatus for displacing logging tools in deviated wells |
US4790377A (en) * | 1986-03-07 | 1988-12-13 | Halliburton Company | Side entry sub well logging apparatus and method |
US4799546A (en) * | 1987-10-23 | 1989-01-24 | Halliburton Company | Drill pipe conveyed logging system |
US5285204A (en) * | 1992-07-23 | 1994-02-08 | Conoco Inc. | Coil tubing string and downhole generator |
US5303775A (en) * | 1992-11-16 | 1994-04-19 | Western Atlas International, Inc. | Method and apparatus for acquiring and processing subsurface samples of connate fluid |
US5377755A (en) * | 1992-11-16 | 1995-01-03 | Western Atlas International, Inc. | Method and apparatus for acquiring and processing subsurface samples of connate fluid |
US5473939A (en) * | 1992-06-19 | 1995-12-12 | Western Atlas International, Inc. | Method and apparatus for pressure, volume, and temperature measurement and characterization of subsurface formations |
US5549159A (en) * | 1995-06-22 | 1996-08-27 | Western Atlas International, Inc. | Formation testing method and apparatus using multiple radially-segmented fluid probes |
US5549162A (en) * | 1995-07-05 | 1996-08-27 | Western Atlas International, Inc. | Electric wireline formation testing tool having temperature stabilized sample tank |
US5587525A (en) * | 1992-06-19 | 1996-12-24 | Western Atlas International, Inc. | Formation fluid flow rate determination method and apparatus for electric wireline formation testing tools |
US5635631A (en) * | 1992-06-19 | 1997-06-03 | Western Atlas International, Inc. | Determining fluid properties from pressure, volume and temperature measurements made by electric wireline formation testing tools |
US5770798A (en) * | 1996-02-09 | 1998-06-23 | Western Atlas International, Inc. | Variable diameter probe for detecting formation damage |
US20010012703A1 (en) * | 1997-10-14 | 2001-08-09 | Tracto-Technik Paul Schmidt Spezialmaschinen | Data transfer system |
US20010013411A1 (en) * | 1999-09-07 | 2001-08-16 | Halliburton Energy Services, Inc. | Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation |
US20010013412A1 (en) * | 1995-02-09 | 2001-08-16 | Paulo Tubel | Production well telemetry system and method |
US20010040030A1 (en) * | 1998-10-27 | 2001-11-15 | Lerche Nolan C. | Downhole activation system |
US20020000317A1 (en) * | 2000-03-17 | 2002-01-03 | Rayssiguier Christophe M. | Communicating with devices positioned outside a liner in a wellbore |
US20020005282A1 (en) * | 1995-06-12 | 2002-01-17 | Weatherford/Lamb, Inc. | Subsurface signal transmitting apparatus |
US20020062991A1 (en) * | 1998-10-27 | 2002-05-30 | Farrant Simon L. | Communicating with a tool |
US20020084913A1 (en) * | 1999-07-07 | 2002-07-04 | Flight Refuelling Limited | Data transmission in pipeline systems |
US20020088623A1 (en) * | 2001-01-09 | 2002-07-11 | Fielder Robert P. | Technique for deploying a power cable and a capillary tube through a wellbore tool |
US6420869B1 (en) * | 2000-10-17 | 2002-07-16 | Baker Hughes Incorporated | Method and apparatus for estimating NMR properties by near infrared spectra |
US20020101359A1 (en) * | 2001-02-01 | 2002-08-01 | Huckaba Bruce S. | Downhole telemetry system having discrete multi-tone modulation and dynamic bandwidth allocation |
US20020104661A1 (en) * | 2000-11-30 | 2002-08-08 | Xl Technology Ltd And Tsl Technology | Telemetering system |
US20020114216A1 (en) * | 2001-02-22 | 2002-08-22 | Veneruso Anthony F. | Method and apparatus for communications in a wellbore |
US20020113718A1 (en) * | 2000-06-22 | 2002-08-22 | Michael Wei | Burst QAM downhole telemetry system |
US20020112860A1 (en) * | 2001-01-26 | 2002-08-22 | Baker Hughes Incorporated | Apparatus and method for electrically controlling multiple downhole devices |
US20020140572A1 (en) * | 2002-02-04 | 2002-10-03 | Gardner Wallace R. | Very high data rate telemetry system for use in a wellbore |
US20020144842A1 (en) * | 2000-11-07 | 2002-10-10 | Schultz Roger L. | System and method for signalling downhole conditions to surface |
US20020163441A1 (en) * | 2001-02-02 | 2002-11-07 | Hill Lawrence W. | Reprogrammable downhole telemetry and control system |
US6478096B1 (en) * | 2000-07-21 | 2002-11-12 | Baker Hughes Incorporated | Apparatus and method for formation testing while drilling with minimum system volume |
US20030006906A1 (en) * | 2001-03-07 | 2003-01-09 | Gardner Wallace R. | Synchronous CDMA telemetry system for use in a wellbore |
US20030048198A1 (en) * | 1999-04-23 | 2003-03-13 | Schultz Roger L. | Self-contained downhole sensor and method of placing and interrogating same |
US20030080743A1 (en) * | 2001-10-29 | 2003-05-01 | Baker Hughes Incorporated | Integrated, single collar measurement while drilling tool |
US6581455B1 (en) * | 1995-03-31 | 2003-06-24 | Baker Hughes Incorporated | Modified formation testing apparatus with borehole grippers and method of formation testing |
US6585045B2 (en) * | 2000-08-15 | 2003-07-01 | Baker Hughes Incorporated | Formation testing while drilling apparatus with axially and spirally mounted ports |
US6607030B2 (en) * | 1998-12-15 | 2003-08-19 | Reuter-Stokes, Inc. | Fluid-driven alternator having an internal impeller |
US6609568B2 (en) * | 2000-07-20 | 2003-08-26 | Baker Hughes Incorporated | Closed-loop drawdown apparatus and method for in-situ analysis of formation fluids |
US20030183384A1 (en) * | 2002-03-26 | 2003-10-02 | Baker Hughes Incorporated | Replaceable electrical device for drilling tool |
US20030184447A1 (en) * | 2001-03-23 | 2003-10-02 | Jens Otterbach | Method for transmitting data from at lest one sensor to a control unit |
US20030196790A1 (en) * | 2002-04-17 | 2003-10-23 | Powell Steven Robert | Control of hydrocarbon wells |
US20030205410A1 (en) * | 2001-07-18 | 2003-11-06 | Koch Geoff D. | Remote control for a drilling machine |
US6683681B2 (en) * | 2002-04-10 | 2004-01-27 | Baker Hughes Incorporated | Method and apparatus for a downhole refractometer and attenuated reflectance spectrometer |
US20040035199A1 (en) * | 2000-11-01 | 2004-02-26 | Baker Hughes Incorporated | Hydraulic and mechanical noise isolation for improved formation testing |
US20040041713A1 (en) * | 1999-02-22 | 2004-03-04 | Richard William Fling | Controlling an underground object |
US6708781B2 (en) * | 2002-05-28 | 2004-03-23 | Schlumberger Technology Corporation | System and method for quantitatively determining variations of a formation characteristic after an event |
US6714138B1 (en) * | 2000-09-29 | 2004-03-30 | Aps Technology, Inc. | Method and apparatus for transmitting information to the surface from a drill string down hole in a well |
US20040154832A1 (en) * | 2003-02-06 | 2004-08-12 | Thomas Koithan | Method and apparatus for controlling wellbore equipment |
US20040156264A1 (en) * | 2003-02-10 | 2004-08-12 | Halliburton Energy Services, Inc. | Downhole telemetry system using discrete multi-tone modulation in a wireless communication medium |
US20040164876A1 (en) * | 2003-02-21 | 2004-08-26 | Halliburton Energy Services, Inc. | Downhole telemetry system using discrete multi-tone modulation having repeated symbols |
US20040163822A1 (en) * | 2002-12-06 | 2004-08-26 | Zhiyi Zhang | Combined telemetry system and method |
US20040168827A1 (en) * | 2002-12-11 | 2004-09-02 | Schlumberger Technology Corporation | System and method for processing and transmitting information from measurements made while drilling |
US20040200639A1 (en) * | 2003-04-09 | 2004-10-14 | Precision Drilling Technology Service Gmbh | Process and device for generating signals which can be transmitted in a well |
US20040207528A1 (en) * | 2003-02-27 | 2004-10-21 | Fabian Carl E. | Miniature magnetomechanical marker for electronic article surveillance system |
US6827149B2 (en) * | 2002-07-26 | 2004-12-07 | Schlumberger Technology Corporation | Method and apparatus for conveying a tool in a borehole |
US20040246142A1 (en) * | 2003-06-03 | 2004-12-09 | Hall David R. | Transducer for downhole drilling components |
US20050001738A1 (en) * | 2003-07-02 | 2005-01-06 | Hall David R. | Transmission element for downhole drilling components |
US20050012637A1 (en) * | 2003-07-14 | 2005-01-20 | Halliburton Energy Services, Inc. | Method and apparatus for mud pulse telemetry |
US20050039923A1 (en) * | 2003-08-21 | 2005-02-24 | Philip Howe | Well control means |
US20050056419A1 (en) * | 2002-11-05 | 2005-03-17 | Hosie David G. | Apparatus for wellbore communication |
US20050087339A1 (en) * | 2003-10-24 | 2005-04-28 | Schultz Roger L. | System and method for processing signals in a well |
US20050087368A1 (en) * | 2003-10-22 | 2005-04-28 | Boyle Bruce W. | Downhole telemetry system and method |
US20050092499A1 (en) * | 2003-10-31 | 2005-05-05 | Hall David R. | Improved drill string transmission line |
US20050145416A1 (en) * | 2004-01-05 | 2005-07-07 | Halliburton Energy Services, Inc. | Method and system of transferring data gathered by downhole devices to surface devices |
US20050161231A1 (en) * | 2002-04-22 | 2005-07-28 | Walter Prendin | Telemetry system for the bi-directional communication of data between a well point and a terminal unit situated on the surface |
US20050167121A1 (en) * | 2002-05-21 | 2005-08-04 | Philip Head | Telemetering system |
US20050183879A1 (en) * | 2002-06-17 | 2005-08-25 | Olav Bakka | Integrated communications and power system |
US20050200497A1 (en) * | 2004-03-12 | 2005-09-15 | Smithson Mitchell C. | System and method for transmitting downhole data to the surface |
US20050205304A1 (en) * | 2002-06-05 | 2005-09-22 | Rishi Gurjar | Tool module connector for use in directional drilling |
US20050231383A1 (en) * | 2004-04-06 | 2005-10-20 | Pratt F D | Intelligent efficient servo-actuator for a downhole pulser |
US20050285754A1 (en) * | 2004-06-28 | 2005-12-29 | Hall David R | Downhole transmission system |
US20050284662A1 (en) * | 2004-06-28 | 2005-12-29 | Hall David R | Communication adapter for use with a drilling component |
US20060027374A1 (en) * | 2002-11-21 | 2006-02-09 | Ludlow Jeremy L C | Electrical transmission system |
US20060044156A1 (en) * | 2004-08-26 | 2006-03-02 | Sarmad Adnan | Well site communication system |
-
2005
- 2005-09-01 US US11/217,185 patent/US20070044959A1/en not_active Abandoned
Patent Citations (88)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3315224A (en) * | 1964-09-01 | 1967-04-18 | Exxon Production Research Co | Remote control system for borehole logging devices |
US4303994A (en) * | 1979-04-12 | 1981-12-01 | Schlumberger Technology Corporation | System and method for monitoring drill string characteristics during drilling |
US4457370A (en) * | 1981-03-13 | 1984-07-03 | Institut Francais Du Petrole | Method and device for effecting, by means of specialized tools, such operations as measurements in highly inclined to the vertical or horizontal well portions |
US4457370B1 (en) * | 1981-03-13 | 1987-01-13 | ||
US4532614A (en) * | 1981-06-01 | 1985-07-30 | Peppers James M | Wall bore electrical generator |
US4597440A (en) * | 1985-04-04 | 1986-07-01 | Schlumberger Technology Corporation | Method and apparatus for displacing logging tools in deviated wells |
US4790377A (en) * | 1986-03-07 | 1988-12-13 | Halliburton Company | Side entry sub well logging apparatus and method |
US4884632A (en) * | 1986-03-07 | 1989-12-05 | Halliburton Logging Services, Inc. | Side entry sub well logging apparatus and method |
US4799546A (en) * | 1987-10-23 | 1989-01-24 | Halliburton Company | Drill pipe conveyed logging system |
US5587525A (en) * | 1992-06-19 | 1996-12-24 | Western Atlas International, Inc. | Formation fluid flow rate determination method and apparatus for electric wireline formation testing tools |
US5473939A (en) * | 1992-06-19 | 1995-12-12 | Western Atlas International, Inc. | Method and apparatus for pressure, volume, and temperature measurement and characterization of subsurface formations |
US5635631A (en) * | 1992-06-19 | 1997-06-03 | Western Atlas International, Inc. | Determining fluid properties from pressure, volume and temperature measurements made by electric wireline formation testing tools |
US5285204A (en) * | 1992-07-23 | 1994-02-08 | Conoco Inc. | Coil tubing string and downhole generator |
US5303775A (en) * | 1992-11-16 | 1994-04-19 | Western Atlas International, Inc. | Method and apparatus for acquiring and processing subsurface samples of connate fluid |
US5377755A (en) * | 1992-11-16 | 1995-01-03 | Western Atlas International, Inc. | Method and apparatus for acquiring and processing subsurface samples of connate fluid |
US20010013412A1 (en) * | 1995-02-09 | 2001-08-16 | Paulo Tubel | Production well telemetry system and method |
US6581455B1 (en) * | 1995-03-31 | 2003-06-24 | Baker Hughes Incorporated | Modified formation testing apparatus with borehole grippers and method of formation testing |
US20020005282A1 (en) * | 1995-06-12 | 2002-01-17 | Weatherford/Lamb, Inc. | Subsurface signal transmitting apparatus |
US5549159A (en) * | 1995-06-22 | 1996-08-27 | Western Atlas International, Inc. | Formation testing method and apparatus using multiple radially-segmented fluid probes |
US5549162A (en) * | 1995-07-05 | 1996-08-27 | Western Atlas International, Inc. | Electric wireline formation testing tool having temperature stabilized sample tank |
US5770798A (en) * | 1996-02-09 | 1998-06-23 | Western Atlas International, Inc. | Variable diameter probe for detecting formation damage |
US20010012703A1 (en) * | 1997-10-14 | 2001-08-09 | Tracto-Technik Paul Schmidt Spezialmaschinen | Data transfer system |
US20020062991A1 (en) * | 1998-10-27 | 2002-05-30 | Farrant Simon L. | Communicating with a tool |
US20010040030A1 (en) * | 1998-10-27 | 2001-11-15 | Lerche Nolan C. | Downhole activation system |
US6607030B2 (en) * | 1998-12-15 | 2003-08-19 | Reuter-Stokes, Inc. | Fluid-driven alternator having an internal impeller |
US20040041713A1 (en) * | 1999-02-22 | 2004-03-04 | Richard William Fling | Controlling an underground object |
US20060012490A1 (en) * | 1999-02-22 | 2006-01-19 | Radiodetection Limited | Controlling an underground object |
US20030048198A1 (en) * | 1999-04-23 | 2003-03-13 | Schultz Roger L. | Self-contained downhole sensor and method of placing and interrogating same |
US20020084913A1 (en) * | 1999-07-07 | 2002-07-04 | Flight Refuelling Limited | Data transmission in pipeline systems |
US20010042617A1 (en) * | 1999-09-07 | 2001-11-22 | Halliburton Energy Services, Inc. | Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation |
US20010013410A1 (en) * | 1999-09-07 | 2001-08-16 | Halliburton Energy Services, Inc. | Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation |
US20010013411A1 (en) * | 1999-09-07 | 2001-08-16 | Halliburton Energy Services, Inc. | Methods and associated apparatus for downhole data retrieval, monitoring and tool actuation |
US20020000317A1 (en) * | 2000-03-17 | 2002-01-03 | Rayssiguier Christophe M. | Communicating with devices positioned outside a liner in a wellbore |
US20020113718A1 (en) * | 2000-06-22 | 2002-08-22 | Michael Wei | Burst QAM downhole telemetry system |
US20050247483A1 (en) * | 2000-07-18 | 2005-11-10 | Koch Geoff D | Remote control for a drilling machine |
US6609568B2 (en) * | 2000-07-20 | 2003-08-26 | Baker Hughes Incorporated | Closed-loop drawdown apparatus and method for in-situ analysis of formation fluids |
US6640908B2 (en) * | 2000-07-21 | 2003-11-04 | Baker Hughes Incorporated | Apparatus and method for formation testing while drilling with minimum system volume |
US6478096B1 (en) * | 2000-07-21 | 2002-11-12 | Baker Hughes Incorporated | Apparatus and method for formation testing while drilling with minimum system volume |
US6585045B2 (en) * | 2000-08-15 | 2003-07-01 | Baker Hughes Incorporated | Formation testing while drilling apparatus with axially and spirally mounted ports |
US6714138B1 (en) * | 2000-09-29 | 2004-03-30 | Aps Technology, Inc. | Method and apparatus for transmitting information to the surface from a drill string down hole in a well |
US6420869B1 (en) * | 2000-10-17 | 2002-07-16 | Baker Hughes Incorporated | Method and apparatus for estimating NMR properties by near infrared spectra |
US20040035199A1 (en) * | 2000-11-01 | 2004-02-26 | Baker Hughes Incorporated | Hydraulic and mechanical noise isolation for improved formation testing |
US20020144842A1 (en) * | 2000-11-07 | 2002-10-10 | Schultz Roger L. | System and method for signalling downhole conditions to surface |
US20020104661A1 (en) * | 2000-11-30 | 2002-08-08 | Xl Technology Ltd And Tsl Technology | Telemetering system |
US20020088623A1 (en) * | 2001-01-09 | 2002-07-11 | Fielder Robert P. | Technique for deploying a power cable and a capillary tube through a wellbore tool |
US20020112860A1 (en) * | 2001-01-26 | 2002-08-22 | Baker Hughes Incorporated | Apparatus and method for electrically controlling multiple downhole devices |
US20020101359A1 (en) * | 2001-02-01 | 2002-08-01 | Huckaba Bruce S. | Downhole telemetry system having discrete multi-tone modulation and dynamic bandwidth allocation |
US20020163441A1 (en) * | 2001-02-02 | 2002-11-07 | Hill Lawrence W. | Reprogrammable downhole telemetry and control system |
US20030010492A1 (en) * | 2001-02-02 | 2003-01-16 | Hill Lawrence W. | Downhole telemetry and control system using orthogonal frequency division multiplexing |
US20030010493A1 (en) * | 2001-02-02 | 2003-01-16 | Hill Lawrence W. | Downhole telemetry and control system |
US20020114216A1 (en) * | 2001-02-22 | 2002-08-22 | Veneruso Anthony F. | Method and apparatus for communications in a wellbore |
US20030006906A1 (en) * | 2001-03-07 | 2003-01-09 | Gardner Wallace R. | Synchronous CDMA telemetry system for use in a wellbore |
US20030184447A1 (en) * | 2001-03-23 | 2003-10-02 | Jens Otterbach | Method for transmitting data from at lest one sensor to a control unit |
US20030205410A1 (en) * | 2001-07-18 | 2003-11-06 | Koch Geoff D. | Remote control for a drilling machine |
US20030080743A1 (en) * | 2001-10-29 | 2003-05-01 | Baker Hughes Incorporated | Integrated, single collar measurement while drilling tool |
US20020140572A1 (en) * | 2002-02-04 | 2002-10-03 | Gardner Wallace R. | Very high data rate telemetry system for use in a wellbore |
US20030183384A1 (en) * | 2002-03-26 | 2003-10-02 | Baker Hughes Incorporated | Replaceable electrical device for drilling tool |
US6683681B2 (en) * | 2002-04-10 | 2004-01-27 | Baker Hughes Incorporated | Method and apparatus for a downhole refractometer and attenuated reflectance spectrometer |
US20030196790A1 (en) * | 2002-04-17 | 2003-10-23 | Powell Steven Robert | Control of hydrocarbon wells |
US20050161231A1 (en) * | 2002-04-22 | 2005-07-28 | Walter Prendin | Telemetry system for the bi-directional communication of data between a well point and a terminal unit situated on the surface |
US20050167121A1 (en) * | 2002-05-21 | 2005-08-04 | Philip Head | Telemetering system |
US6708781B2 (en) * | 2002-05-28 | 2004-03-23 | Schlumberger Technology Corporation | System and method for quantitatively determining variations of a formation characteristic after an event |
US20050205304A1 (en) * | 2002-06-05 | 2005-09-22 | Rishi Gurjar | Tool module connector for use in directional drilling |
US20050183879A1 (en) * | 2002-06-17 | 2005-08-25 | Olav Bakka | Integrated communications and power system |
US6827149B2 (en) * | 2002-07-26 | 2004-12-07 | Schlumberger Technology Corporation | Method and apparatus for conveying a tool in a borehole |
US20050056419A1 (en) * | 2002-11-05 | 2005-03-17 | Hosie David G. | Apparatus for wellbore communication |
US20060027374A1 (en) * | 2002-11-21 | 2006-02-09 | Ludlow Jeremy L C | Electrical transmission system |
US20040163822A1 (en) * | 2002-12-06 | 2004-08-26 | Zhiyi Zhang | Combined telemetry system and method |
US20040168827A1 (en) * | 2002-12-11 | 2004-09-02 | Schlumberger Technology Corporation | System and method for processing and transmitting information from measurements made while drilling |
US20040154832A1 (en) * | 2003-02-06 | 2004-08-12 | Thomas Koithan | Method and apparatus for controlling wellbore equipment |
US20040156264A1 (en) * | 2003-02-10 | 2004-08-12 | Halliburton Energy Services, Inc. | Downhole telemetry system using discrete multi-tone modulation in a wireless communication medium |
US20040164876A1 (en) * | 2003-02-21 | 2004-08-26 | Halliburton Energy Services, Inc. | Downhole telemetry system using discrete multi-tone modulation having repeated symbols |
US20040207528A1 (en) * | 2003-02-27 | 2004-10-21 | Fabian Carl E. | Miniature magnetomechanical marker for electronic article surveillance system |
US20040200639A1 (en) * | 2003-04-09 | 2004-10-14 | Precision Drilling Technology Service Gmbh | Process and device for generating signals which can be transmitted in a well |
US20040246142A1 (en) * | 2003-06-03 | 2004-12-09 | Hall David R. | Transducer for downhole drilling components |
US20050001738A1 (en) * | 2003-07-02 | 2005-01-06 | Hall David R. | Transmission element for downhole drilling components |
US20050179560A1 (en) * | 2003-07-14 | 2005-08-18 | Halliburton Energy Services, Inc. | Method and apparatus for mud pulse telemetry |
US20050012637A1 (en) * | 2003-07-14 | 2005-01-20 | Halliburton Energy Services, Inc. | Method and apparatus for mud pulse telemetry |
US20050039923A1 (en) * | 2003-08-21 | 2005-02-24 | Philip Howe | Well control means |
US20050087368A1 (en) * | 2003-10-22 | 2005-04-28 | Boyle Bruce W. | Downhole telemetry system and method |
US20050087339A1 (en) * | 2003-10-24 | 2005-04-28 | Schultz Roger L. | System and method for processing signals in a well |
US20050092499A1 (en) * | 2003-10-31 | 2005-05-05 | Hall David R. | Improved drill string transmission line |
US20050145416A1 (en) * | 2004-01-05 | 2005-07-07 | Halliburton Energy Services, Inc. | Method and system of transferring data gathered by downhole devices to surface devices |
US20050200497A1 (en) * | 2004-03-12 | 2005-09-15 | Smithson Mitchell C. | System and method for transmitting downhole data to the surface |
US20050231383A1 (en) * | 2004-04-06 | 2005-10-20 | Pratt F D | Intelligent efficient servo-actuator for a downhole pulser |
US20050285754A1 (en) * | 2004-06-28 | 2005-12-29 | Hall David R | Downhole transmission system |
US20050284662A1 (en) * | 2004-06-28 | 2005-12-29 | Hall David R | Communication adapter for use with a drilling component |
US20060044156A1 (en) * | 2004-08-26 | 2006-03-02 | Sarmad Adnan | Well site communication system |
Cited By (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20090242274A1 (en) * | 2004-06-18 | 2009-10-01 | Schlumberger Technology Corporation | Apparatus for measuring streaming potentials and determining earth formation characteristics |
US8302687B2 (en) | 2004-06-18 | 2012-11-06 | Schlumberger Technology Corporation | Apparatus for measuring streaming potentials and determining earth formation characteristics |
US20100071910A1 (en) * | 2008-09-25 | 2010-03-25 | Nicholas Ellson | Method and system for using wellbore instruments with a wired pipe string |
US20100300685A1 (en) * | 2009-06-01 | 2010-12-02 | Del Campo Christopher S | Method and system for using wireline configurable wellbore instruments with a wired pipe string |
US8136591B2 (en) | 2009-06-01 | 2012-03-20 | Schlumberger Technology Corporation | Method and system for using wireline configurable wellbore instruments with a wired pipe string |
US20110164999A1 (en) * | 2010-01-04 | 2011-07-07 | Dale Meek | Power pumping system and method for a downhole tool |
US10208558B2 (en) | 2010-01-04 | 2019-02-19 | Schlumberger Technology Corporation | Power pumping system and method for a downhole tool |
US10385682B2 (en) | 2016-08-15 | 2019-08-20 | Baker Hughes, A Ge Company, Llc | Pipe conveyed logging and drill pipe communication integration system and method |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA2474998C (en) | Well system | |
US7881155B2 (en) | Pressure release encoding system for communicating downhole information through a wellbore to a surface location | |
US5458200A (en) | System for monitoring gas lift wells | |
CN101929335B (en) | The concentrated sampling of formation fluid | |
EP2042683B1 (en) | A logging while producing apparatus and method | |
US8245781B2 (en) | Formation fluid sampling | |
US8905128B2 (en) | Valve assembly employable with a downhole tool | |
US8022838B2 (en) | Logging system, method of logging an earth formation and method of producing a hydrocarbon fluid | |
US11180965B2 (en) | Autonomous through-tubular downhole shuttle | |
US20130222149A1 (en) | Mud Pulse Telemetry Mechanism Using Power Generation Turbines | |
AU2018343099A1 (en) | A well in a geological structure | |
US8824241B2 (en) | Method for a pressure release encoding system for communicating downhole information through a wellbore to a surface location | |
US20070044959A1 (en) | Apparatus and method for evaluating a formation | |
WO2012094242A2 (en) | Method for a pressure release encoding system for communicating downhole information through a wellbore to a surface location | |
US20200232313A1 (en) | Downhole component support systems and methods of installation | |
US20210381327A1 (en) | Logging a well |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: BAKER HUGHES INCORPORATED, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:GEORGI, DANIEL;REEL/FRAME:016975/0388 Effective date: 20050831 |
|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |